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Home My WebLink About187-004Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Tuesday, April 28, 2020 5:43 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: KRU 3Q-02 (PTD 187-004) Update Hi Chris, KRU injector 3Q-02 (PTD 187-004) was recently reported for IA pressurization. Logging diagnostics identified the source of the IA pressurization to be a leak in the tubing. The IA pressure has stabilized at 1450 psi. CPAI continues to develop a path forward for repair and will submit the appropriate sundry requests related to the repair. The well will remain shut- in and freeze protected. Sincerely, Sam, Ca-Usl& (fiPr�c+'.vv) /SteppPadv Well Integrity & Compliance Specialist, WNS & CP173 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549@cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Sunday, April 5, 2020 11:56 AM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU 3Q-02 (PTD 187-004) IA Pressure Increase Chris, KRU injector 3Q-02 (PTD 187-004), which has been reported previously for IA pressurization and was about to start a monitor period on water injection, was brought online yesterday following a well line upgrade. (It had been shut in since 8/9/19.) On night shift the IA pressure was found to be at 1900 psi and the operator was unable to get the IA pressure to bleed down. The well was shut in and freeze protected. Diagnostics are in progress. Upon conclusion of diagnostics a follow up email with the plan forward and any required paperwork will be submitted. Attached are a 90 day TIO trend and a wellbore schematic. Please let me know if you have any questions or disagree with this plan. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Sunday, August 25, 2019 4:24 PM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: RE: KRU 3Q-02 (PTD 187-004) Monitor Plan Update Chris, KRU 3Q-02 was brought on water injection for less than a month before being shut-in for the CPF3 plant shutdown. Our intent, was to continue the monitor after the shutdown. However, 3Q-02 utilizes uninsulated hardline at surface for injection. Due to impending cold weather and risks of freezing, Operations plans to discontinue injection and rig down the hardline for the foreseeable future. If surface piping is set-up to allow water injection into the well in future, CPAI will plan to restart the water injection monitor. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Friday, July 5, 2019 1:28 PM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU 3Q-02 (PTD 187-004) Monitor Plan Update Chris, KRU 3Q-02 (PTD 187-004) is an injector that our Operations group plans to bring on water injection in the near future. Our last communication with you about this injector was in February 12, 2016 when we initially reported the well for anomalous IA pressurization during gas injection and an intent to perform a monitor. However, the well has been shut-in since that time due to downhole fish and a problematic SSSV flapper. CPAI intends to start with water injection for up to 90 days to monitor the well and confirm integrity exists on water injection. If TxIA during water injection is identified, then the well will be shut-in. Otherwise, CPAI will follow-up with a path forward at the end of the monitor period. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Sunday, April 5, 2020 11:56 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 3Q-02 (PTD 187-004) IA Pressure Increase Attachments: 3Q-02 Schematic.pdf, 3Q-02 90 Day TIO Trend 4-5-20.pdf Chris, KRU injector 3Q-02 (PTD 187-004), which has been reported previously for IA pressurization and was about to start a monitor period on water injection, was brought online yesterday following a well line upgrade. (It had been shut in since 8/9/19.) On night shift the IA pressure was found to be at 1900 psi and the operator was unable to get the IA pressure to bleed down. The well was shut in and freeze protected. Diagnostics are in progress. Upon conclusion of diagnostics a follow up email with the plan forward and any required paperwork will be submitted. Attached are a 90 day TIO trend and a wellbore schematic. Please let me know if you have any questions or disagree with this plan. Regards, Stephanie Pilch / alt: Sara Carlisle CPF3 & Alpine Well Integrity & Compliance Specialist ConocoPhillips Alaska Office: (907) 659-7126 From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Sunday, August 25, 2019 4:24 PM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: RE: KRU 3Q-02 (PTD 187-004) Monitor Plan Update Chris, KRU 3Q-02 was brought on water injection for less than a month before being shut-in for the CPF3 plant shutdown. Our intent, was to continue the monitor after the shutdown. However, 3Q-02 utilizes uninsulated hardline at surface for injection. Due to impending cold weather and risks of freezing, Operations plans to discontinue injection and rig down the hardline for the foreseeable future. If surface piping is set-up to allow water injection into the well in future, CPAI will plan to restart the water injection monitor. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Friday, July 5, 2019 1:28 PM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU 3Q-02 (PTD 187-004) Monitor Plan Update Chris, KRU 3Q-02 (PTD 187-004) is an injector that our Operations group plans to bring on water injection in the near future. Our last communication with you about this injector was in February 12, 2016 when we initially reported the well for anomalous IA pressurization during gas injection and an intent to perform a monitor. However, the well has been shut-in since that time due to downhole fish and a problematic SSSV flapper. CPAI intends to start with water injection for up to 90 days to monitor the well and confirm integrity exists on water injection. If TxIA during water injection is identified, then the well will be shut-in. Otherwise, CPAI will follow-up with a path forward at the end of the monitor period. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Sunday, August 25, 2019 4:24 PM To: Wallace, Chris D (CED) Cc CPA Wells Supt Subject: RE: KRU 3Q-02 (PTD 187-004) Monitor Plan Update Chris, KRU 3Q-02 was brought on water injection for less than a month before being shut-in for the CPF3 plant shutdown. Our intent, was to continue the monitor after the shutdown. However, 3Q-02 utilizes uninsulated hardline at surface for injection. Due to impending cold weather and risks of freezing, Operations plans to discontinue injection and rig down the hardline for the foreseeable future. If surface piping is set-up to allow water injection into the well in future, CPA[ will plan to restart the water injection monitor. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Friday, July 5, 2019 1:28 PM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n103O@conocophillips.com> Subject: KRU 3Q-02 (PTD 187-004) Monitor Plan Update Chris, KRU 3Q-02 (PTD 187-004) is an injector that our Operations group plans to bring on water injection in the near future. Our last communication with you about this injector was in February 12, 2016 when we initially reported the well for anomalous IA pressurization during gas injection and an intent to perform a monitor. However, the well has been shut-in since that time due to downhole fish and a problematic SSSV flapper. CPAI intends to start with water injection for up to 90 days to monitor the well and confirm integrity exists on water injection. If TxIA during water injection is identified, then the well will be shut-in. Otherwise, CPAI will follow-up with a path forward at the end of the monitor period. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 MEMORANDUM To: Jim Regg P.I. Supervisor FROM: Matt Herrera Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 24, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc, 3Q-02 KUPARUK RIV UNIT 3Q-02 Sre: Inspector Reviewed By: y'f: P.I. Supry �p Comm Well Name KUPARUK RIV UNIT 3Q-02 API Well Number 50-029-21688-00-00 Inspector Name: Matt Herrera Permit Number: 187-004-0 Inspection Date: 7/21/2019 ' Insp Num: mitMFH 190723150454 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I 3Q-02 Type Inj I W jTVD PTD 1870040 " Type Test SPTTest psi BBL Pumped: 2.5 BBL Returned: 6148 Tubing 1948 _ 1951 - 1950 1951 IA mo z8os - z74o ma OA 304. 495 - 495 495 537 24 Interval 4YRTST P/P P x Notes: MIT -IA to 2800 PSI Per Operator -Te-53-djj-e- Qf In` SIVLCC- P161`[ xv� 2v Ko Wednesday, July 24, 2019 Page I of I Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Friday, July 5, 2019 1:28 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 3Q-02 (PTD 187-004) Monitor Plan Update Chris, KRU 3Q-02 (PTD 187-004) is an injector that our Operations group plans to bring on water injection in the near future. Our last communication with you about this injector was in February 12, 2016 when we initially reported the well for anomalous IA pressurization during gas injection and an intent to perform a monitor. However, the well has been shut-in since that time due to downhole fish and a problematic SSSV flapper. CPAI intends to start with water injection for up to 90 days to monitor the well and confirm integrity exists on water injection. If TxIA during water injection is identified, then the well will be shut-in. Otherwise, CPAI will follow-up with a path forward at the end of the monitor period. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, February 12, 2016 9:00 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: KRU 3Q-02 (PTD 187-004) Report of anomalous IA pressurization Attachments: 3Q-02.pdf; 3Q-02 90 day TIO trend 2-12-16.JPG Chris, KRU WAG Injector 30-02 (PTD 187-004) was shut in today after experiencing anomalous IA pressurization while on gas injection. DHD will perform the initial round of diagnostics to include an MITIA, pack off tests, and an IA draw down test. Depending upon the outcome of the initial diagnostics the well will either be brought on gas or water injection for a 30 day monitor period. Upon conclusion of the diagnostics and monitor period a follow up email with the plan forward and any required paperwork for corrective action or continued injection will be submitted. Attached is a 90 day TIO trend and wellbore schematic. Please contact us if you disagree or have any questions with the plan. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 SCANNED MAY 1 9 2096 Pager(907) 659-7000 pgr. 123 ifitELLS TEAM Ca,« lips 1 • • d waltamoq CD CD o O CN1— .1 ,I ,1 ,I ,I ,I ,I „ ,: + : „ : { . f `--..,___ . : ,- '-• - • �_- r - I. \ -1r 1 • • • ti , b 5 1 co I . i (o • • . I I i • I : I - i )1 • CO CNI - '• `; - r • • • \ , --) • • I • • 21 -,.. ; , . : �- 0,4 I- CNI - • • _ • I 5 I - {j\ • -- • 5 • • j : : li 0 I -,_ r7 • : CL a 1, • Z a_ ' 1 _ 6 I •• • c • I' I' 1' I' I' l' 3' i' I' 1 I I' f f N ' ► r i ~ < o CD 0 CD O w O 0 1--- CO (+] (N r ISd Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. j__ ~ r']_ D ~ L~ Well History File Identifier ' Organization (done) RESCAN [] Color items: Grayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES: ? ? NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL PrOject Proofing DATE: OVERSIZED (Scannable) D Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other ~SI [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: lei PAGES: C[(~ (at the time of scanning) SCANNED BY'- ~BREN VINCENT SHERYL MARIA LOWELL DATE: RESCANNED BY; BEVERLY BREN VINCE~ARIA LOWELL General Notes or Comments about this file: PAGES: Quality Checked {done) RevlNOTScanned.wpd ! Cono ~ ' ' coPhill~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ S~, a ~w..w. . ~ff~~. ~ ~ ~~~ ~~ ~ ~ ~~ ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with 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 treatrnents took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~' 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9~` and 10~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~G~ MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 08/11109 ~~ ~~ ~~ o ~., ~_~ ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date ,,..~ Corrosion inhibitor , o.. Corrosion inhibitod sealant date bbls a~ 3G-12 50103209310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" n/a 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8/2009 3H-10B 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3N-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" . n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" Na 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF n/a 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8!8/2009 3Q-02 3Q-04 50029216880000 50029222190000 1870040 1911240 41' 4'10" 4.75 1.50 21" 16" 7/30/2009 7/30/2009 5.52 4.25 8/8/2009 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 3Q-13 50029296770000 50029216640000 1861890 1861760 7" 44'6" n/a 5.00 7" 21" n/a 7/30/2009 2.97 8.92 8/8/2009 8/8/2009 3Q-15 50029216660000 1861780 49'S" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7/30/2009 8.5 8/8/2009 MEMORANDUM To: Jim Regg ~e~~ ~ ~ + (~~ P.I. Supervisor ' 1 I FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 01, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3 Q-02 KUPARUK RIV UNIT 3Q-02 Src: Inspector NON-CONFIDENTIAL Reviewed i'pn P.I. Suprv4 1 r~` Comm Well Name: xuPARUx RIV uNrt 3Q-o2 API Well Number: so-o29-21688-00-0o Inspector Name: Bob Noble Insp Num: mitRCN080927180755 Permit Number: 187-004-0 ./ Inspection Date: 9/25/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 3Q-oz Type Inj. W TVD 6149 IA 1660 3000 ~ 2940 ~ 2930 p.T ~ Is7oo4o TypeTest SPT Test psi 3000 / OA ~ sIO e6o X60 X60 Interval 4YRTST p~F P / Tubing zzoo zzoo zzoo zzoo ~ Notes: _ +~,i ~` ~ ~`~ R `" ~z'~~~ Wednesday, October O1, 2008 Page i of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission FROM: John Crisp Petroleum Inspector DATE: Wednesday, August 11,2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-02 KUPARUK RIV UNIT 3Q-O2 TO: Jim Regg ~e¿ <ì>(ztt (iYt P.I. Supervisor r Src: Inspector Reviewed By: P.I. Suprv :::J3f-- Comm Well Name: KUPARUK RIV UNIT 3Q-02 API Well Number: 50-029-21688-00-00 Inspector Name: John Crisp Insp Num: mitJCrO4081 0 170825 Permit Number: 187-004-0 Inspection Date: 8/812004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Q-02 Type Inj. S TVD 6509 IA 360 2200 2170 2160 P.T. 1870040 TypeTest SPT Test psi 1537.25 OA 0 0 0 0 Interval 4YRTST P/F P Tubing 2800 2800 2800 2800 Notes: NON-CONFIDENTIAL Wednesday, August 11,2004 Page 1 of I I MEMORANDUM TO: Julie Huesser, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission ? '~'-;~'~ DATE: December 1, 2000 THRU: Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 3Q Pad Friday, December 1: 2000: ! traveled to 3Q Pad in the Kuparuk River Field and witnessed the safety valve system testing on 4 miscellaneous WAG injectors. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 4 wells and 8 components with one failure observed. The pilot on well 3Q- 21, which had just been brought line and was not fully up to operating temp, tripped well below the required trip pressure. This pilot was retested upon completion of today's testing and operated properly. Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with Summary: I witnessed the SVS testing of 4 WAG injectors at 3Q Pad in the Kuparuk River Field. KRU 3Q Pad, 4wells, 8 components, 1 failure Attachment: SVS KRU 3Q Pad 12-1-00 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 3Q Pad 12-1-00 CS.doc Alaska Oil and GaS Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Operator Rep: Emie Bamdt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupamk / KRU / 3Q Pad Separator psi: LPS HPS 12/1/00 Well ' Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 3Q-Ol 1911250 . 3Q-02 1870040 3700 2000 1750 P P WAG 3Q-03 1911260 . 3Q-04 1911240 3Q-06 1861950 · . 3Q-07 1861940 3Q-08A 1971930 3Q-09 1861860 · 3Q-10 1861870 , 3Q-11 1861880 3Q-12 1861890 3700 2000 1900 P P WAG , 3Q-14 1861770 , 3Q-22 1951860 3Q-16 1861790 3700 2000 2000 P P WAG 3Q-21 1951930 3700 2000 1200 3 P 12/1/00 WAG Wells: 4 Components: 8 Failures: 1 Failure Rate: [] 9o oar Remarks: Misc tests on Wag wells 12/4/00 Page 1 of 1 SVS KRU 3Q Pad 12-1-00 CS.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pull tubing _ Alter casing _ Repair well _ Perforate _X Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development __ Exploratory__ Stratigraphic__ Service__X 4. Location of well at surface 2205' FNL, 2352' FEL, Sec.17, T13N, R9E, UM At top of productive interval 810' FNL, 2587' FEL, Sec.19, T13N, R9E, UM At effective depth (asp's 515983, 6025867) (asp's 510487, 6021974) At total depth 982' FNL, 2910' FEL, Sec.19, T13N, R9E, UM (asp's 510166, 6021801) 12. Present well condition summary Total depth: measured true vertical 9993 feet 6510 feet Plugs (measured) Effective depth: measured 9640 feet true vertical 6295 feet Casing Length Size CONDUCTOR 115' 16" SURF CASING 5224' 9-5/8" PROD CASING 9804' 7" Junk (measured) Cemented 1875# Poleset 1450 Sx AS III & 350 G 300 Sx Cl G 6. Datum elevation (DF or KB feet) RKB 59 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3Q-02i 9. Permit number / approval number 187-004 10. APl number 50-029-21688 11. Field / Pool Kuparuk Oil Pool Tagged PBTD (3/1/00) @ 9640' MD. Measured Depth 115' 5283' 9863' True vertical Depth 115' 3697' 6431' Perforation depth: measured 9530 - 9546'; 9556 - 9610' true vertical 6228 - 6238'; 6244 - 6277' Tubing (size, grade, and measured depth) 2.875", 6.5#, J-55, Tubing @ 9430' MD. Packers & SSSV (type & measured depth) Baker 'HB' Packer @ 9400' MD. Otis FMX Not Fully Locked Out 3/1/00; 3/12/00 - Set 2.31 Frac Sleeve, Min ID 2.0" @ 1789' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mci Water-Bbl - 1898 1888 CasingPressure TubingPm~um 2863 2860 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations ._X 16. Status of well classification as: Oil __ Gas __ Suspended _ Service __(WAG)~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Form 10-404 Rev 06/15/88 · Signed t./. f- ~ f - ", % Prepared~;J~ohn Peirce 265-6471 "~ ~ SUBMIT IN DUPLICATE 3Q-02i PEFIFOFIATING OPEFIATIONS DE$OFIIPTION OF WOFIK OO~PLETED 3/1/00: RIH & tagged PBTD at 9640' MD. 8/5/00: MIRU & PT equipment. RIH w/perforating guns & shot 20' of perfs in the 'A-2' Sand as follows: Added perforations: 9590 - 9610' MD Used 1-11/16" carrier & shot the perfs at 6 spf. POOH w/guns. RD. 8/9/00: MIRU & PT equipment. RIH w/perforating guns & shot 20' of perfs in the 'A-I' Sand as follows: Added perforations: 9530 - 9546' MD Used 1-11/16" carrier & shot the perfs at 6 spf at zero degree phasing. POOH w/guns. RD. Returned the well to Water injection & obtained a valid injection rate. MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 28, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 WELL 1 H-07 3G-04 3Q-0.2 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparu'k field. The wells are listed below. ACTION Other Stimulate Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Gas ConS. Anchorage AR3B-6003-93 242-2603 SI'ATE OF: - , ~ OIL AND C-.-.-.-.-.-.-.-.-~ ~VATION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing , Alter casing .. Repair well 2. Name of Operator 5. Type of Well: Development ARCO Alaska. Inc. Exploratory 3. Address Stratigraphic P. O. Box 100360, Anchorage, AK 99510 Serv~e X 4. Location of well at surface 2205' FNL, 2352' FEL, SEC.17, T13N, R9E, UM At top of productive interval 810' FNL, 2587' FEL, SEC. 19, T13N, R9E, UM At effective depth 900' FNL, 2755' FEL, SEC.19, T13N, R9E, UM At total depth 982' FNLr 2910' FELt $EC.19~ T13Nr R9Er 12. Present well condition summary Total Depth: measured UM 9993' true vertical 6509' Effective depth: measured 9 7 72' true vertical 6 3 74' Casing Length Size Structural Conductor 8 0' 1 6" Surface 5 2 4 6' 9 5/8" Intermediate Production 9 8 2 8' 7" Liner Perforation depth: measured 9556'-9590' true vertical 6244'-6265' feet Plugs (measured) feet None feet Junk (measured) feet None Perforate Other __ 6. Datum elevation (DF or KB) RKB 50' 7, Unit or Property name Kuparuk River Unit 8. Well number 3Q-02 feet g. Permit number/Al~proval Number 10, APl number 5o-029-2168800 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Cemented Measured depth True vertical depth 1875# Poleset 1 1 5' 1 1 5' 1450 Sx AS III & 5283' 3697' 350 Sx Class G 300 Sx Class G 7329' 6539' RECEIVED MAR t994 Oil & Gas Cons. Commission Anchorage Tubing Pressure Tubing (size, grade, and measured depth) 2-7/8" 6.5# J-55 SM modified tubing @ 9430' Packers and SSSV (type and measured depth) $SSV: Otis FMX ~ 1789', PACKER: Baker HB ~ 9401' 13. Stimulation or cement squeeze summary A SAND FRACTURE TREATMENT ON INJECTOR Intervals treated (measured) 9556'-9590' Treatment description including volumes used and final pressure SEE ATTACHED WELL SERVICE REPORT SUMMARY 14. Fleoresentafive Daily ~.veraqe Production or Iniecfion Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 0 Subsequent to operation 0 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X . Oil __ Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S~ned ~)~~' ~ Title Sr. En.qineer Form 10-404 Rev 09/12/90 0 694 880 2603 0 1556 880 2686 16. Status of well classification as: Suspended Service WATER INJECTOR SUBMIT IN DUPLICATE MORNING REPORT SUMMARY 01/29/94 TO 01/29/94 CPF-3 DS-3Q 39-02 01/29/94 A SAND REFRAC W/ DS: PUMPED 150 BBL BD @ 30 BPM, MAX PRES = 8800 PSI, FWHTP = 8632 PSI, ISIP = 2664 PSI, FG = 0.87, EXCESS FRIC = 310 PSI. PUMPED 700 BBL PAD @ 20 BPM, FOLLOWED BY 736 BBL SLURRY, 16/20 - 2PPA, 12/18 - 2-14 PPA. CONTINUALLY CUTTING RATE F/ 20-7 BPM TO STAY BELOW MAX TREAT PRES. LOSING TURBINES AS PUMP RATE DECREASED. WENT TO FLUSH. BEGINNING OF 14 PPA STAGE AS VALVE PROBLEMS DEVELOPED ON LAST TURBINE. FLUSHED TO COMPLETION. TOT PROP PUMPED: 162.9 MLBS (181.7 MLBS DESIGN), 161.0 MLBS IN FORM (8.1M LBS 16/20), 1.6M LBS IN WELLBORE. EFF PAD/SLURRY 95%. FLUIDS USED: 1241BBL SEAWATER, 75 BRA DSL, 82 BBL ADDITIVES. (FITZPATRICK/GOLDEN/KIRBY/HABLISTON) RECEIVEE? ARCO Alaska, Ir Subsidiary of Atlantic Richfield Compa, WELL WELL SERVICE REPORT PBDT IDATE 9772. [DAYS CONTRACTOR : FoA u tFIELD - DISTRICT- STATE OPERATION AT REPORT TIME J~B ~AaPLETE REMARKS --- FRACTURE ~?O0-//~0 /W//eLt Z)OWEZL FRAC £~P'~ /-/0~ ~AFETY A4TG. ?IPE? ~,) ~C FLU/DS. IA/$7'ALZ (SAVE~. P~I/4E Pu/.4P,s ~ TEST/./dES TO 950o 761, 074, IZO0 P/..I/,4P 15'0/~,6L ,.~/..ICKIyltTt:.-~, B~EAKDOWA~ ~ ,51 ~/~ 8800 ?al..[S.[P ~64 751. iZ35 Pu~P 7o0 i~43 P/X/AP 84>90z. z~.~, /~,z/2z) ~ /..¢4~,¢? ~$. /Z//$ CA£SO/_/TE ~ 18- 7 8P~ ZOW l~tt~ £ATE ~ D~oI~PIN~ 77) .f. PI, h4,IP ON MA}E, }~EL~tT~VEL¥ LA~GE VOL. PROP. /555 F~u sH 17oo 5//.T. WELL. EST ', ~ i£z 4-79 KUPARUK PE-rROLEUM ENGiNEERiNG r--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather tTomP'Report °F Chill Fact°r I VisibilitY°F milos twind Vol' knots Signed ARCO Alaska, Inc. Post Office B~A 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 29, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate is a Report of Sundry Well Operations for the well listed below. WELL ACTION 3Q-02 Other If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J. R, Brandstetter ATO 1120 S. M. Renke ATO 1126 KOE1.4-9 w/o attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Al{?,[t ~;003 C STATE OF ALASKA ALASKA OIL AND GAS ~SERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown . Pull tubing , ,, Alter casing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2205' FNL, 2352' FEL, Sec. 17, T13N At top of productive interval 810' FNL, 2587' FEL, Sec. 19, T13N, At effective depth 900' FNL, 2755' FEL, Sec. 19, T13N, At total depth 982' FNL~ 2910' FEL~ Sec. 19~ T13N~ 12. Present well condition summary Total Depth: measured 9 true vertical 6 Stimulate ~ Repair well 5. Type of Well: Development Exploratory Stratigraphic Service X'-- , R9E, UM R9E, UM R9E, UM Plugging . Perforate _ Other X 6. Datum elevation (DF or KB) 60' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3Q-02 9. Permit number/approval number 90-867 10. AP I number so-029-21688 feet R9E~ UM 993' 509' 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool feet Plugs (measured) feet Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length 80' 5246' 9772' 6374' Size 16" 9-5/8" 9828' 7" measured 9556'-9590' true vertical 6244'-6265' 12 SPF feet Junk (measured) feet Cemented Measured depth 1875# Poleset I 1 5' 1450 Sx AS III & 5283' 350 Sx Class G 300 Sx Class G 7329' 120 degree phasing Tubing Pressure Tubing (size, grade, and measured depth) 2 7/8" 6.5# J-55 SM modified tubing set @ 9430' Packers and SSSV (type and measured depth) Otis FMX SSSV @ 1789'~ Baker HB packer @ 9401' 13. Stimulation or cement squeeze summary Converted well from oil production to water injection Intervals treated (measured) 9556'-9590' Treatment description including volumes used and final pressure Reoresentative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure True verti~l depth 115' 3697' 6539' 14. Prior to well operation 65 36 349 1100 115 Subsequent to operation 0 0 3 0 0 0 5 0 0 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run ~ I Water Injector 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. Sic~lned'~~'~'''%1~)'''~ ' ~A'/~''~ Title ~-/P~; ~rL-" ~)~ Form 10-404 Rev 09/12/90 2750 Service ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL ~6~ -2 CONTRACTOR REMARKS IPBDT q55~ FIELD- DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT 07oo-- l-I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Inc.~ Subsidi&ry of Atlantic Richfield Company WELL CONTRA~CTOR REMARKS IPBDT q5 5~ WELL SERVICE REPORT FIELD - DISTRICT- STATE OPERATION AT REPORT TIME mm, t t~o,- I'[.t$ - {"'3 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~A~CO Alaska, Inc. ~ul~ldllty of Atl~ntio Rlchf~tcl Company WELL CONTRACTOR REMARKS WELL SERVICE REPORT FIELD - J~ISTRICT - STATE IOPERATION AT REPORT TIME I'"1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program X Plugging _ Pull tubing _ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4, Location of well at surface 2205' FNL, 2352' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 810' FNL, 2587' FEL, Sec. 19, T13N, R9E, UM At effective depth 900' FNL, 2755' FEL, Sec. 19, T13N, R9E, UM At total depth 982' FNL, 2910' FEL, Sec. 19, T13N, R9E, UM 1¸2. Present well condition summary Total Depth: measured true vertical 9993' 6509' Operation Shutdown _ Re-enter suspended well _ Time extension _ Stimulate m Variance _ Perforate Other 6. Datum elevation (DF or KB) Plugs (measured) feet feet 60' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3Q-02 9. Permit number 87-4 10. APl number 5o-029-21688 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool None 13', i4, Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 9 7 7 2' true vertical 6374' Length Size 80' 16" 5246' 9 -5/8" 9828' 7" measured 9556'-9590' 12 SPF feet feet Junk (measured) None Cemented Measured depth True vertical depth 1875# Poleset 115' 115' 1450 Sx AS III & 5283' 3697' 350 Sx Class "G" 300 Sx Class "G" 9863' 6429' 120 degree phasing true vertical 6244'-6265' Tubing (size, grade, and measured depth 2 7/8", 6.5# J-55 AB mod. tubing set at 9430' Packers and SSSV (type and measured depth) Baker HB pkr. @ 9401'r Otis FMX SSSV ~ 1789' Attachments Description summary of proposal_ Convert well from oil production to water injection Estimated date for commencing operation January. 1991 If proposal was verbally approved Name of approver Date approved RE( EIVED O EC 1 1 199[ Alaska 011 & Gas Cons. C0mmiss[O~ Anchorage Detailed operation program X BOP sketch _ 15. Status of well classification as: Oil m Gas m Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic~ned .~, ~, ~ Title Operations Engr. FOR COMMISSION USE ONLY COndi{iOns of approval' Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance - _ Mechanical Integrity Test Subsequent form require Approved Copy Returned .......... Appr.oved by the order of the Commission 10- ~/ Commissioner Date Date~,. ~. / /?¢~, ,,, IApproval No. Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIE C. SMITH SUBMIT IN TRIPLICATE Kuparuk Well 3Q-02 Waterflood Conversion Procedure AFE #899381 1. Shut-in well for 48 hours. 2. MIRU slickline unit and pressure test equipment. 3. RIH and tag fill. 4. RIH with Panex memory gauge to 9560' MD-RKB (or as deep as possible based on tag) and record bottom hole pressure for 30 minutes. If Panex is not available use an Amerada bomb for the pressure measurement. 4. Pull GLVs from GLMs @ 3226', 7120', 8826', and 9341' MD-RKB and run DVs in GLMs @ 3226', 7120', and 8826' MD-RKB. 5. Displace 7" annulus with diesel. 6. Run DV in GLM @ 9341' MD-RKB. 7. RDMO slickline unit. 8. Perform MIT test. The state must be notified at least two days prior to performing the MIT test. Note' Contact Operations Engineering prior to initiating water injection in Well 3Q-02 in order to confirm that State approval and Ballot approval have been obtained. REEEIVED DEC 1 1 1990 Alaska 0il & Gas Uons. uumm~ss~o~ Anchorage 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF 2 t E ,EIVE DEC Alasl~a Oil & (~as Corzs. Commission Anchorage N]REL]hlE BOP EI~U]PHENT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Pull tubing X Alter casing Stimulate __ Plugging Perforate Repair well X Other__ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2205' FNL, 2352' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 810' FNL, 2587' FEL, Sec. 19, T13N, R9E, UM At effective depth 900' FNL, 2755' FEL, Sec. 19, T13N, R9E, UM At total depth 982' FNL, 2910' FEL, Sec. 19, T13N, R9E, UM '12. Present well condition summary Total Depth: measured 9 9 9 3' feet true vertical 6509' feet Plugs (measured) 6. Datum elevation (DF or KB) 59' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3Q-2 9. Permit number/approval number 87-4/90-577 10, APl number 50-029-21688 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 9 7 7 2' feet true vertical 6374' feet Junk (measured) Casing Length Size Structural Conductor 8 0' 1 6" Surface 524 6' 9 - 5 / 8" Intermediate Production 8098' 7" Liner Perforation depth: measured 9556'-9590' md true vertical 6243'-6264' tvd Cemented 1875 lbs Poloset 1450 Sx AS III & 350 Sx Class G 300 Sx Class G Tubing (size, grade, and measured depth) 2-7/8", 6.5 #, J-55 @ 9430' Packers and SSSV (type and measured depth) Baker 'HB' Retr Pkr @ 9401' wlm, Otis 'FMX' SSSV @ 1789' md 13. Stimulation or cement squeeze summary Measured depth 115' 5283'md 9863'md True vertical depth 115' 3697'tvd 64298'tvd Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 1 (~-404 Rev/ 05/-17/89 Title Area Drilling Engineer SUBMIT IN DUPLICATE ARCO Oil ~... Gas Company Well History - Initial Report - Daily 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 County, parish or borough NORTH SLOPE ILease or Unit ITitle i~DL: 25512 ALK: 2553 WORKOVER IState AK J Well no. 3~-2 KUPARUK RIVER UNIT Auth. or W.O, no. AK5083 Operator ARCO SpuddedsPuDOr W.O. begun JDate 2/4/87 IHOur IARCO WI. 55.2521 IPrior status ~f a W.O. Date and depth Complete record for each day reported as of 8:00 a.m. NORDIC #1 08/19/90 ( TD: 0 PB: 9773 SUPV:DEB 08/20/90 ( TD: 0 PB: 9773 SUPV:DEB 08/21/90 ( TD: 0 PB: 9773 SUPV:DEB 08/22/90 ( TD: 0 PB: 9773 2) 3) 4) POH 7"@ 9863' MW: 8.4 NaCl ACCEPT RIG @ 1200 HRS, 8/18/90, RU LINE TO TREE CAP TO DISPLACE & KILL WELL BLEED GAS OFF TBF, KILL WELL, CIRC SEAWATER DOWN TBG TO OPEN GLM @ 8832', TAKE RETURNS OUT ANNULUS THRU CHOKE TO OUTSIDE TANK, TBG DEAD, INJECT 10 BBLS SW TO FORMATION, CONTINUE CIRC TILL SW RETURNS, SD & MONITOR, WELL DEAD, SET BPV ND TREE, NU BOPE, PULL BPV, SET TP, CHANGE PIPE RAMS TO 2-7/8", Nil FLOW NIPPLE TEST BOPE & ETC. TO 3000 PSI, PULL TP, MU LNDG JT, TEST PIPE RAMS & ANNULAR TO 3000 PSI, BOLDS, PULL FMC 2-7/8" HGR TO FLOOR, PU @ 52K, DRAGGING UP TO 60K, LD HANGER, MU CIRC HEAD, CIRC HOLE VOL THRU OPEN CHOKE TO MAKE SURE WELLBORE FLUIDS BELOW GLM @ 8832 TO OEJ ARE DISPLACED. POH W/2-7/8" COMP ASSY, CHANGE SEAL RINGS, DRIFTING, TALLY TBG, LD SSSV & GLM'S. DAILY:S21,100 CUM:S21,100 ETD:S21,100 EFC:$155,000 POH W/ 2-7/8" TBG 7"@ 9863' MW: 8.4 NaC1 FPOH, CHANGE SEAL RINGS, DRIFT, TALLY TBG, LD JEWELRY, SERVICE RIG, STOOD BACK 136 STANDS, LD 15 JTS & PUP ON TOP OF OEJ DUE TO HELICAL BUCKLING, PROGRESSIVE MORE SEVERE TOWARDS BTM, BREAK CONN OEJ & LD & REDRESS, LOAD & STRAP NEW TBG, MU OEJ, I JT TBG, GLM W/ 48/64" CV, FINISH TBG DETAIL, CONTINUE RIH, PU NEW TBG, TAG OBSTRUCTION @ 470' MD,RU HEADPIN & BREAK CIRC & TURN PIPE 1/4 TURN CONTINUE RUNNING 2-7/8" CA, JEWELRY & 287 JTS, PU SINGLE & LD JT TO TAG SLICK STICK/PKR FOR SPACE OUT, RAN DEEPER THAN EXPECTED & DID NOT TAG, LD 24' LD JT & USED SINGLE ABOVE, TAG PKR @ 9486', HAS DROPPED TO FILL ON BTM, PU TO 88K MAX PULL, NO MOVEMENT, PUT PUMP ON TBG, PKR BROKE FREE, BREAK CIRC, LD 4 SINGLES USED, POH W 2-7/8" CA, LD JEWELRY, STAND BACK TBG, POH @ 600 DAILY:S38,179 CUM:$59,279 ETD:S59,279 EFC:$155,000 POH FTA #1 7"@ 9863' MW: 8.4 NaCl SERVICE RIG, FINISH POH W/ COMP. ASSBY, MU FTA#i, RIH AND TAG TOP OF OEJ AT 9479', MAX PULL 260K#, CBU AT 4 BPM, POH W/ FTA#I DAILY:S29,314 CUM:$88,593 ETD:S88,593 EFC:$155,000 RUNNING 2-7/8" C.A. 7"@ 9863' MW: 8.4 NaCl SERVICE RIG, FINISH POH W/ FTA#i, RECOVERED OEJ SLICK STICK AND PACKER AND ALL TAILPIPE, MU BIT AND BHA#I, RIH. ~iNG ~t~u~mK ~EVERAL TIMES PAST PACKER SETTING DEPTH, CBU, POH AND LDDP, RUN 2-7/8" COMP ASSBY DAILY:S34,174 CUM:$122,767 ETD:S122,767 EFC:$155,000 The above is correct Signature~/ i I' . X /. __ IOate . -- For form preparatio~and~lis-tr~'but'ion, ~ ' I ' see Procedures ~a~ual S~ction 10 ( ~ Drilling, Pages 86'"a~L.~, ~ AR3B-459-1-D INumberall daily well history forms consecutively no. as they are prepared for each well. I~Page I ARCO O,..,nd 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 opera[ions are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and repFesentative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District State ARCO ALASKA INC. AK Field KUPARUK RIVER UNIT Auth. or W,O, no, AK5083 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. ICounty or Parish NORTH St, OPE Lease or Unit ,aDZ,: 25512 AZ,[4:2553 Title WORKOVER J Well no, 3q-2 08/23/90 ( TD: 0 PB: 9773 SUPV:GB A.R.Co. W.I. Date 55. 2521 J 2/4/87 Complete record for each day reported NORDIC #1 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our J Prior status if a w.o. I RIG RELEASED 7"@ 9863' MW: 0.0 Diesel FIN RUN COMP STRING, 287JTS, 8 GLM'S, BAKER PKR ASSY, CAMCO "D" NIPPLE, OTIS SSSV, & FMC TBG HGR, RU OTIS S.L., RUN & SET 2.25" CAT STANDING VALVE IN "D" NIPPLE. POOH W/SL & RD OTIS, SET BAKER 'HB' PKR, SHEAR PBR, RELAND TBG, TEST ANNULUS/PKR W/2500 PSI F/15 MIN, TEST SSSV F/15 MIN, CLOSE SSSV, SET BPV, ND STACK, NU TREE, TEST PACK-OFF & TREE TO 5000PSI, RU LINES & DISPLACE SEAWATER IN WELL WITH 336 BBLS DIESEL, CHECK CV IN GLM, CV HOLDING, SITP = 600PSI, SICP = 0 PSI, SECURE WELL, TRANSFER FULID FROM RIG PITS & RIG WATER TANK TO DIRTY BRINE TANK, MOVE RIG OFF WELL, CLEAN WELLHEAD & LOCATION, RELEASE RIG @ 0130 HRS 8/23/90 DAILY:S44,858 CUM:$167,625 ETD:S167,625 EFC:$155,000 Old TD Released rig Classifications (oil, gas, etc.) Producing method Potential test data New TD PB Depth Date K nd of r g Type completion (single, dual, etc.) Off ciat reservo r name(s) Well no. Date Reservoir Producing Interval Oil 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 For ,O, *,epar I~n an~dis, rib;,io~, AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well, jPage no. DIvlNon of AtlanflcRIchfleldCompsny TO: THRU: FROM: MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COFR~ISSION Lonnie C. Smi DATE: August 31, 1990 Commissioner FILE NO: 3T. DA. 831.1 TELEPHONE NO: Doug ~o~ Petroleum Inspector SUBJECT: BOPE/RIG Inspection AAI KRU 3Q-Nordic Rig 1 Kuparuk Rv Fie 1 d Tuesday .Aug_ ~I_,_ 1990: I traveled this date from Anchorage to AAI' s KuParUk~Rv Field to conduct an inspection for threaded connection in the lines downstream of the choke manifold on Nordic Rig No. 1. I found hammer unions in the vent line from the choke manifold to the well cleanout tank. I spoke with Don Breeden, AAI rep., and gave him a copy of Mike Minder's memo dated 1/3/90 reaffirming the Commission's decision not to allow any threaded connection in the lines downstream of the choke manifold. After this discussion, Don contacted his parts warehouse and ordered clamps to replace ali. the hammer unions in question. I will conduct further inspections to insure the parts are properly installed and the rig is brought into complicance. In summary: I conducted the BOPE/RIG Inspection at AAI's KRU drillsite 3Q on Nordic Rig No. I. 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 STATE OFALASKA0 R 16 I A [ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 . Abandon Suspend Operation Shutdown Re-enter suspended well_ Alter ca~ing _ Repair wel~_ Plugging _ Tim;' extension _ Stimulate ~( Change approved program Pull tubing _ Variance Perforate Other 6. Datum elevation (DF or KB) Location of well at surface 2205' FNL, 2352' FEL, At top of productive interval 810' FNL, 2587' FEL, Sec. 19, T13N, At effective depth 900' FNL, 2755' FEL, Sec. 19, T13N, At total depth 982' FNL, 2910' FEL, Sec. 19, T13N, 5. Type of Well: Development Exploratory Stratigraphic Service 12. Sec. 17, T13N, R9E, UM R9E, UM R9E, UM R9E, UM Present well condition summary Total Depth: measured 9 true vertical 6 993' feet Plugs (measured) 509' feet 60' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3Q-02 9. Permit number 87-4 10. APl number 50-029-21688 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool None Effective depth: measured 9772' feet Junk (measured) true vertical 6374' feet Casing Length Size Cemented Structural Conductor 8 0' 1 6" 1875# Poleset Surface 5 2 4 6' 9 - 5 / 8" 1450 Sx AS III & Intermediate 350 Sx Class "G" Production 9 8 2 8' 7" 300 Sx Class "G" Liner Perforation depth: measured 9556'-9590' 12 SPF 120 degree phasing None Measured depth True vertical depth 115' 115' 5283' 3697' 9863' 6429' true vertical 6244'-6265' Tubing (size, grade, and measured depth 2 7/8", 6.5# J-55 AB mod. tubing set at 9475' Packers and SSSV (type and measured depth) Camco HRP-1-SP pkr. ~ 9414'~ Camco TRDP-1A-SSA SSSV ~ 1795' Attachments Description summary of proposal _ Detailed operation program ~X Hydraulically refracture the A sand. BOP sketch 14. Estimated date for commencing operation Se.Dt~mber 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas __ Service Suspended 17. I he.by certify( that the foregoing is true and correct to the best of my knowledge. Si~lned =~~& ~ Title Sr. Operations Engr. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval~No. Plug integrity _ BOP Test Mechanical Integrity Test _ Location clearance Subsequent form r'-~quire 10- Approved by the order of the Commission Form 10-403 Rev 5/03/89 Approved CopY .Returned ;. .... ......... ,, SUBMIT IN TRIPLICATE ORIGINAL SIGNED BY Application for Sundry Approval Kuparuk Well 3Q-02 September 11th, 1990 1. The estimated bottom hole pressure is 2900 psig at-6200' ss. 2. No workover fluids will be required for refracturing the well. Kuparuk Well 3Q-02 Refracture Treatment ISTAGE BREAKDOWN (BBL) (POUNDS) PROPPANT (LBS)II (BBL) IDIRTY VOL (BBL] PERFS @ (BBL) 150 0 0 150 150 58 MAX. WHPT (PSI) 7600 ...................................... SHUT DOWN FOR ISIP ...................................... PAD 900 0 0 900 1050 208 7600 SLURRY 2 PPA 4 PPA 6 PPA 7 PPA 8 PPA 10 PPA 12 PPA 64 5404 5404 70 1120 1108 68 11425 16829 80 1200 1178 71 17936 34765 90 1290 1258 76 22467 57233 100 1390 1348 74 24840 82072 100 1490 1348 42 17490 99562 60 1550 1448 13 6593 106155 20 1570 1548 7400 7200 6900 6800 6700 6400 6200 FLUSH 25 33 TOTAL 1517 VOLUME TO PERFS (BBL) = 0 0 106155 58.0 ........ - Proppant- 12/18M Carbo-lite or LWP 106155 25 1595 106155 33 1628 1628 Pump rate = 20 bpm (drop to 16 bpm if necessary) Estimated surface treating pressure = 4750 psi (includes perf friction) Breakdown = GW + 40 PPT silica flour + 8 hour breaker (cut XL during last 50 bbls.) Pad = GW + 40 PPT silica flour + 8 hour breaker 6200 6800 Slurry = GW + 8 hour breaker (no silica flour) Flush = 10 bbls. GW + 8 hour breaker (no silica flour) followed by 46 bbls. of slick diesel Kuparuk Well 3Q-02 A Sand Refrac Procedure Cost Tracking AFE: # K81344 Pre-Frac 1. Perform CTU cleanout to PBTD. 2. Obtain at least two 12 hour well tests. 3. Tag fill to confirm that well was effectively cleaned out below the bottom of the perforated interval. 4. Gauge tree and tubing hanger using a gauge ring with a large enough O.D. to ensure that the tree saver can be set. 5. Pull GLVs from 3226', 7120', 8826', and 9341' MD-RKB and run DVs @ 3226', 7120', and 8826' MD-RKB. 6. Displace 7" annulus with diesel. 7. Run Petredat gauge if available (set up to record tubing pressure) @ 9341' MD-RKB. Otherwise, run DV @ 9341' MD-RKB. 8. Pressure test 7" annulus to 2500 psi. F ra ct v re ,'l',~,ea t me n t Quality Control: 1. Check all tanks for cleanliness uncontaminated. and check proppant for fines. Insure water is 2. Insure adequate proppant and water are on location for the frac. 3. Perform pre-frac quality control tests on gelled water using water which has been delivered to the drill site for the frac. Frac Job: 1. MIRU fracturing equipment. Install tree saver and pressure test all surface lines. . Pressure up 2-7/8" x 7" annulus to 3300 psi. Do not allow this pressure to exceed 3500 psi during fracture treatment. Maximum allowable wellhead treating pressures for each fluid stage of the fracture treatment are shown on the attached pump schedule, assuming an annulus pressure of 3500 psi. . Pump 150 barrel gelled water breakdown stage, shut-down for ISIP, and check for excess friction. Check tank straps against flow meter and correct flush volume as necessary. . Pump fracture treatment per attached schedule starting with a 900 barrel gelled water 'pad. The following gelled water systems (delayed cross-link HPG based gel) are acceptable for the refracture treatment: Halliburton: Hybor Dowell: YF240D B.J. Titan: TFR II 5. The expected treating pressure is 4750 psi. 6. Bleed down annulus to 500 psi. Rig down fracturing equipment. AL/- ~ OIL AND GAS CONSERVATION COMM, 3N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well X Plugging _ Change approved program _ Pull tubing X 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 99510 Operation Shutdown _ Re-enter suspended well _ Time extension _ Stimulate _ Variance _ Perforate _ Other 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 2205' FNL, 2352' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 810' FNL, 2587' FEL, Sec. 19, T13N, R9E, UM At effective depth 900' FNL, 2755' FEL, Sec. 19, T13N, R9E, UM At total depth 982' FNL, 2910' FEL, Sec. 19, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 9993' feet Plugs (measured) 6 5 0 9' feet None 6. Datum elevation (DF or KB) RKB 59 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3Q-2 9. Permit number 87-4 10. APl number 50-029-21 688 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 9772' feet Junk (measured) 6 3 7 4' feet None Casing Length Size Structural Conductor 8 0' 1 6" Surface 5 24 6' 9 5/8" Intermediate Production 9 8 2 8' 7" Liner Perforation depth: measured 9556'-9590' MD Cemented Measured depth 1875# Poloset 1 1 5' 1 1 5' 1450 Sx AS III & 5283' 3697' 350 Sx Class G 300 Sx Class G 9863' 6429' true vertical 6243'-6264' TVD Tubing (size, grade, and measured depth 2-7/8", J-55 set at 9475' MD Packers and SSSV (type and measured depth) HRP-1-SP pkr @ 9414' TRDP-1A-SSA SSSV @ 1795' 13. Attachments Description summary of proposal _ Repair damaged (possibly buckled) tubing above packer 14. Estimated date for commencing operation 15. August 7. 1990 16. If proposal was verbally approved Name of approver Date approved True vertical depth .eECL:iVED Detailed operation program X BOP sketch X Status of well classification as: Oil ~( Gas __ Suspended Service Pro d u c e r 17. I certify that the foregoing is true and correct to the best of my knowledge. [.) FOR COMMISSION USE ONLY Date IConditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require . Original SIgned E~y Approved by the order of the Commission David W. J(~hrl§t(~fl 10- 4'O~/ Commissioner Form 10-403 Rev 06/15/88 Approvect Copy IApproval I 7,, SUBMIT IN TRIPLICAIE 11" 5000 PSI BOP STA K 6 5 1. 9-5/8" CASING HEAD 11" -3000 PSI FLANGE 2. 11" - 3000 PSI X 7 1/6" - 5000 PSI TUBING HEAD 3. 7 1/6" - 5000 PSI X 11" 5000 PSI CROSS-OVER SPOOL 4. 11" -5000 PSI BLIND RAMS 5. 11" -5000 PSI PIPE RAMS 6. 11" -5000 PSI ANNULAR . . . 10. 11. 12. 13. 14. 15. ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED 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 FILL BOP STACK AND MANIFOLD WITH BRINE. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 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. 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. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE 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 FUNCTIONALLY OPERATE BOPE DAILY. A~'l~hO[8~ SRE 9/89 Kuparuk River Unit Well 3Q-2 Preliminary Workover Procedure Replace Buckled Tubing Pre-Rig Operations 1. Obtain surface pressure buildup to confirm BHP. 2. RU E-line and perforate tubing above restriction or pull DV from GLM. 3. Set BPV. Rig Operations 1. MIRU Nordic #1. Displace well with seawater. ND tree. NU BOPE. 2. POH with tubing. Lay down damaged tubing. 4. Pickup new tubing as necessary. Rerun completion assembly. 5. Release rig. ARCO Alaska, Inc. Date: ' December 8, 1988 Transmittal #: 7365 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 G- 01 Kuparuk Fluid Level Report I 2 - 0 5 - 8 8 Casing 3Q-02 Kupaurk Fluid Level Report 1 1 - 2 9 - 8 8 Casing 3 K - 0 6 Kuparuk Fluid Level Report 1 1 - 2 7 - 8 8 Casing 2 V- 0 4 Kuparuk Well Pressure Report 1 1 - 1 6 - 8 8 Sand 'A' 2V-04 Kuparuk Well Pressure Report 11 -1 9-88 Sand 'A° Receipt Acknowledged' DISTRIBUTION: D&M State of Alaska Chevron Mobil Unocal SAPC ARCO Alaska, Inc. Date: October 7, 1988 Transmittal #: 7314 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3Q-02 Kuparuk Fluid Level Report(4:20) 1 0- 0 2- 8 8 $Q-02 Kuparuk Fluid Level Report(3:10) 1 0-02-88 2 D- 01 Kuparuk Fluid Level Report 1 0 - 0 2 - 8 8 I Y- 1 6 Kuparuk Fluid Level Report 1 0- 0 2 - 88 $A-01 Kuparuk Fluid Level Report(3:55) 1 0-02-88 3A-01 Kuparuk Fluid Level Report(4:45) 1 0- 0 2- 8 8 1 F-05 Kuparuk Fluid Level Report 1 0-04-88 1 F- 08 Kuparuk Fluid Level Report I 0- 0 4 - 8 8 1 F- 02 Kuparuk Well Pressure Report 9-30-88 Casing Casing Casing Casing Casing Casing Tubing Tubing Amerada Oil & Gas Cons. CommissJor~ Anchorage Receipt Acknowledged' - .......................... Date' - ........... DISTRIBUTION: D&M State of Alaska Chevron Unocal Mobil SAPC ARCO Alaska, In(, Pos! Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 15, 1987 Transmittal #:6054 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3C-16 Kuparuk River Unit 'A' Sand 100598H' 8-26. thru30-87 2Z-1 Kuparuk River Unit 'A' Sand 100557H 8-31 thru9-2-87 3Q-2 Kuparuk River Unit PBU 100559H 8-25 thruS-29-87 3M-12 Kuparuk Well Pressure Report(Otis) Static A Sand 9-3-87 3M-13 Kuparuk Well Pressure Report(Otis) Static A Sand 8-28-87 3M-14 Kuparuk Well Pressure Report(O'tis) Static A Sand 9-1-87 1Y-14 Kuparuk Well Pressure Report(Camco) C Sand 8-23-87 1Y-6 Kuparuk Well Pressure Report(Otis) 8-21-87 1Y-5 Kuparuk Well Pressure Report(Otis) Static C Sand 8-23-87 1Y-16 Kuparuk Well Pressure Report (Otis) 8-21-87 1Y-11 Kuparuk Well Pressure Report (Otis) Static 8-21-87 1Y-9 Kuparuk Well Pressure Report (Otis) 8-21-87 1Y-3 Kuparuk Well Pressure Report (Otis) Static C Sand 8-22-87 2X-14 Kuparuk Well Pressure Report (Otis) Static C Sand 7-18-87 2Z-1 Kuparuk Well Pressure Report (Otis) Static C Sand 7-2-87 2X-lO Kuparuk Well Pressure Report (Otis) C Sand 7-19-87 · Receipt ~cknowledged: DISTRIBUTION: Gas Cons. Commission Anchorage D&M ,~.<~State' of'Alaska BPAE Chevron Mobil SAPC ARCO Alaska, Inc, Is a Subsidiary of AtlanlicRIchlleldCompany Unocal STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION C~,MMISSION .~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL IX] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-4 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21688 "4. Location of well at surface 9. Unit or Lease Name 2205' FNL, 2352' FEL, Sec.17, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 810' FNL, 2587' FEL, Sec.19, T13N, RgE, UM 3Q-2 At Total Depth 11. Field and Pool 982' FNL, 2910' FEL, Sec.19, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 59'I ADL 25512 ALK 2553 ,, 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 02/04/87 02/11/87 04/27/87WI N/A feet MS L 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9993'MD, 6509'TVD 9772'MD, 6374'TVD YES [~ NO []I 1795' feet MD 1600' (approx.) 22. Type Electric or Other Logs Run D IL/SFL/SP/Cal/GR/FDC/CNL, CBL/CCL/GR, 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" 62.5#' H-40 Surf 115' 24" 1875# Pol eset 9-5/8" 36.0# J-55 Surf 5283' 12-1/4" 1450 sx AS Ill & 350 sx Class G 7" 26.0# J-55 Surf 9863' 8-1/2" 300 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) 2-7/8" 9475 ' 9414 ' .,. 9556'-9590'MD perforated w/12 spf, 6243 '-6264 'TVD @ 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMouNT& KIND OF MATERIA~USED See attached adde~dum~ dated 5/5/87 for fracture Jata 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lith'ology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None iv A¥ ~ NOTE: Drilled RR 02/13/87. Perforated we]]& tubing run 03/07/87. Form 10-407 WC261 :DANI Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE _ ~/ 29. i 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GaR, and time of each phase. Top Kuparuk C 9532' 6228' N/A Truncated Base Kuparuk C 9532' 6228' Truncated Top Kuparuk A 9532' 6228' Base Kuparuk A 9654' 6303' 31. LIST OF ATTACHMENTS Addendums (dated 3/19/87 and 5/5/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~('~tj~'~/}(~'' ~/~)~J.,C/)'~A ~,) Title Associate Engineer Date '-~'-/~---~--~ 7' INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 2/17/87 3Q-2 RU Gearhart, rn CBL/CCL/GR f/9752'-7843'. Rn GR/JB to 9755'. Rn gyro. RD Gearhart. Drilling fupervisdr ' DAte ADDENDUM WELL: 3Q-2 4/27/87 Frac Kuparuk "A" sand perfs 9556'-9590' per procedure dated 4/24/87 in 13 stages as follows: Stage 1: 40 bbls 140° diesel w/5% Musol @ 4 - 5 BPM, 4385-4800-4450 psi Stage 2: 100 bbls gel diesel @ 10-16-20 BPM, 6530- 5900-5100 psi Stage 3a: 38 bbls gel diesel, 20 BPM, 5230-5300 psi Stage 3b: 140 bbls gel diesel @ 20 BPM, 5500-4500 psi Stage 4: 11 bbls gel diesel 1 ppg 100 mesh @ 20 BPM, 4500 psi Stage 5: 309 bbls gel diesel @ 20 BPM, 4500 - 4390 psi Stage 6: 19 bbls gel diesel 2 ppg 16/20 @ 20 BPM, 4390 - 4320 psi Stage 7: 18 bbls gel diesel 3 ppg 16/20 @ 20 BPM, 4320 - 4565 psi Stage 8: 35 bbls gel diesel 4 ppg 16/20 @ 20 - 19.5 BPM, 4565 - 4955 psi Stage 9: 34 bbls gel diesel 5 ppg 16/20 @ 19.5 BPM, 4955 - 4860 psi Stage 10:33 bbls gel diesel 6 ppg 16/20 @ 19.5 BPM, 4860 - 5040 psi Stage 11:16 bbls gel diesel 7 ppg 16/20 @ 19.5 - 19 BPM, 5040 - 5130 psi Stage 12:15 bbls gel diesel 8 ppg 16/20 @ 19 BPM, 5130 - 5190 psi Stage 13:56 bbls gel diesel flush @ 19 - 19.5 BPM, 5190 - 4590 psi Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 864 bbls 500# 100 Mesh & 34,400# 16/20 carbo prop 280# 16/20 4800 psi Well released to Production. Drilling Supervisor Date ex ADDENDUM WELL: 4/27/87 8/02/87 3Q-2 Frac Kuparuk "A" sand perfs 9556'-9590' per procedure dated 4/24/87 in 13 stages as follows: Stage 1: 40'bbls 140° diesel w/5% Musol @ 4 - 5 BPM, 4385-4800-4450 psi Stage 2: 100 bbls gel diesel @ 10-16-20 BPM, 6530- 5900-5100 psi Stage 3a: 38 bbls gel diesel, 20 BPM, 5230-5300 psi Stage 3b: 140 bbls gel diesel @ 20 BPM, 5500-4500 psi Stage 4: 11 bbls gel diesel 1 ppg 100 mesh @ 20 BPM, 4500 psi Stage 5: 309 bbls gel diesel @ 20 BPM, 4500 - 4390 psi Stage 6: 19 bbls gel diesel 2 ppg 16/20 @ 20 BPM, 4390 - 4320 psi Stage 7: 18 bbls gel diesel 3 ppg 16/20 @ 20 BPM, 4320 - 4565 psi Stage 8: 35 bbls gel diesel 4 ppg 16/20 @ 20 - 19.5 BPM, 4565 - 4955 psi Stage 9: 34 bbls gel diesel 5 ppg 16/20 @ 19.5 BPM, 4955 - 4860 psi Stage 10:33 bbls gel diesel 6 ppg 16/20 @ 19.5 BPM, 4860 - 5040 psi Stage 11:16 bbls gel diesel 7 ppg 16/20 @ 19.5 - 19 BPM, 5040 - 5130 psi Stage 12:15 bbls gel diesel 8 ppg 16/20 @ 19 BPM, 5130 - 5190 psi Stage 13:56 bbls gel diesel flush @ 19 - 19.5 BPM, 5190 - 4590 psi Fluid to Recover: sand in Zone: Sand in Csg: Avg Pressure: 864 bbls 500# 100 Mesh & 34,400# 16/20 carbo prop 280# 16/20 4800 psi Well released to Production. '-~ Arctic Pak w/175 sx AS I & 60 bbls Arctic Pak. Tst OK. x~ \ .~. February 26, 1987 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-70019 Well: 3Q-2 Field: Kuparuk North Slope, Alaska Survey Date: February 16, 1987 Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NL Sperry. Sun/NL Industries, Inc. RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 KUF'ARUK ALA.:,KA VERT I,_-:AL SEC:T I ON ,'":~'LT:O'E~'Y~':,' ~'~Eii, i%" CLo'.:iEii iE ........ SF'ERRY--SL.IN WELL Sl...IF:::VEYIIqE. i COMF'ANY F'.~GE 1 .................................................................................................. 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DEF TH DEPTFI EJIE;F'I'FI DE(:.~ I'11 N COMF'Lll'ATI ON DATE F:'EBRI..IA R Y 1 'i;;', 1 i;;'E:'7 COIJRF:E D IRECTI ON I')EGREE;S DOG-LEG S E ViE IR i T Y I]E G / 100 .................... F2A_C~E . 4_ I]ATF OF .:,LRVEY FEBRUARY 16 1987 BI}SS GYRO.'F.;COPIC: SLIRVEY J 0 B N LI M B E R A K- B C - '7 ()019 KEL. I...Y BLISHING ELEV. = OF'ERATOR-MC:C:iLI IRE TOTAL. R 15; C 'T A N G U I.,.. A R C: 0 Ei R D I N A 'T E S NORTH/SC~IJ]"H E: A'.:].; ]" / W E E;'F VERT I~ II--; I'!" # ,=, ,=. 0 U 574 :--:. 0 ....... 9 .=,/., ::: 9 . o. '-.?. 4 ..., =' 22 :3900 58.1. 8.79 5'759.77 44 :39 900C) .5,'F.::39. _':.i:C) 58G:0, 20 ,q. 5 51 ..................... 9. 100 .-,'--"-'::, .--.," ...... / ......... ..,=' :?: f'] :::':~ ::: 5 ::: 4 '7 .'q, .... ............................. 9150 5990.71 59 :.--.: 1.71 48 52 '.-.-F200' ........ 6023. :27 .................... 596'4 :'27 ......... 49" 5'i- ';,:::00 .... 608/_-, .2'-.? ...... 1-,027 .2'--.~. ':;'-'._~: 0 9400 6.1. 47.55 6088.55 5'.:...':-25 9500 62 C)8.59 6149.59 52 20 ? 600 6269.69 6210.69 5:2 20 .... 9700 6:':~:30_ .6::: 6271 . 6:3 ._,='-"..- :2::_:: 980'(.5 ..... C-,:3'.:.} I. 4:3 ............ 6!7~:}--:2.4:3 52" :3:3 ~" ' ' _ ..... 52 .. ~/(-)¢) t",4-~:;'.~' ':.!:2 /:,393.22 :3:3 ,.--,,Y~'9o -/-, .'--; C) R ...... '7/S 6449 76 ._...-"-'-' .:,.z:'-"- ..................... HORI ZF'INTAL. DISPLACEMENT = '.:..; Zl..5. C) W .'.:s 48. :3'P W S 53.5() W c. ,=;,::, 0 W · ..! ._ ,_~ · E; r"]8. :_::9 W S 60. 19 W S z .:, 0 c ..... 1 W S /::.?.. 0 W :.--.; /o2. ,./:,9 W '..-3 62. i'P W S 61. :-q'?:' W S 61. E:':.? W :---; 61.:F:9 W 7109. 1-_, ~' F E:. E T A T SO LI :3 11 :::::,' 01.84 o ~--:.-,,-- ........... ,.:,._, 1. :2:9 W 0.4:3 :38:37.66 .:"'; 542' 1.84 W 0. '1: =' :."-.'::::7 . 549 . ..'.-, 3 81 S 2::3:3 W 0.40 :5:'? 10.4:3 S .5',...,~-,,.- ~': '_ '7.'. N_ 2_ W 0. :32 :F.:94. 7.59 :_--; 56:3'2.55 W 0.00 :39:3'4 .- 9 iL_-:'- ':~i ................. 5702.59 ' W 0.00 4C.)22.38 S 5772.63 W 0 0¢] 4 ('~.~ 7 1/-, S .~]'-"-' . ......... >o7 7'7 N ..................................... TH...,=:"-'._, I)EG. 12 MIN. WEST AT MD = 99'p:E: 61~7.3.9 6198,06 6267.98 6338.76 6411.75 6449.09 6 486. 6564.05 6642.35 6720 ,:,t- i *--' --* 6799. :3'? 6956.96 7035.82 710~.15 THE DALCLLATION F'ROC:EISijRi~-'~I~;E--BAi~E[~ nN ]'HE OsE ,-,F THREE DIMENSIONAL RADIUS OF C1]ROA-TIjRE METHOD, ARCO ALASKA~ 3Q-2 KUF'ARLIK ALASKA I NC:. ':: t' ~' E I"~ R Y- '3 U N W E I.... I... i": I..It';: V E Y I I',10 C' 0 H I"" ¢t I',1Y ANCHFU:~AF~E AL_ASI<A E: 0 M F'I._I 1' A T 101"4 I] A T E FEBF;:I..IARY J '.:/, .I. ':::':.::7 DATE OF :5;URVEY FEBRUARY 16, !.987 I<EI_I_.Y BU'._:;HING ELEV. = 0 F' E R A T 0 R- M C G iJ I R E MEASURED DEPTH ............ INTERPF~LATED VALUES FOR EVEN 1¢)0(') FEET FIF MEA.:,_KED DEPTH TRLIE SLIB-SEA ]"CFI'AL .... VER'T I CAL VERT I CAL I-REC]'ANGLIL AR CO01-~D I NATES MD- TVK~ VERT I F':AI_ K.I E F' T H D E F:' T H Ixl I:'.t R T I---I / S L-I I_1T FI E A '.:; T / W E'.:-; T D I F F E R E N C E ' F: Fi R R E C: T I 0 N .: 0 ('), () 0 - 5'....-/. 0 ('~ 0, 00 0.00 1000 F-'78, '.:.;'7 'PI 9. ?7 44.8'.:.;' S 1.38. 'F.'O W · 2000 1. '78:_:: 1 '.-? ............ i"~!24'~'"~ '? ................... 2;--:2. '.:.';'7 .:, c, 71. :[ 4 W :30 O, 0 24. C, 8.40 234 '.-.-,'. 4 O, 73'F/. 22 S 1. 30:3.61 W ............................................. 4 C, 00 2'?':? 6. 'F,' 6 2'? 37. 'P 6 117'P. 7:3 S 1 !:? 81.20 W ..... ~:":0~5 ......... :3548 .':":; ::: ...... '-' '-"--,'""='-" .......... :, 4,:, ..: , ._,.:, 160 ./:,. 66 '._:.; 2697.34 W 6000 4077.2:3 40,18. '::.'3 2077, 40 S :340:3.4¢::, W 7000 464. 0 "::;'":' ~ o .%.-:,. .-, =,"-. - 4 ..... 1 ._ .. ..... : .......... ·.....,:. · ..: .... .:¢(..~, '-'::"'-."'," '-' 4,:'~,'::'],A 75W ........ '",'~:(i~ii:i .... .5 :2 :::: '.:? . ('.,F~ 5 ~ 80 .' i)i~: ....... :31 ::F.:F.:. 3:3 t.-..; 4;'::,:...-::4. '7!:;' W '.:.;'000 58:_:.':'.:.), 20 58:3C.~..'--':0 :3./:,85. 18 :.:.'; :51. 58. 1 .'.-':' 1,4 ...... ':~':~ 9":,' ¢.-,' ..., '=,.''~ ,-,'-' -x/., 644':?. 76 4057 i/-, :i.:.; '--'-'"" 7 '77 N .- o.. - .... ~ z _ . - . l t--,."! ':' 1 (')::: '-' 1 ()::: 21 ~. :L:: I 1 ';? 5. '78 5':? 1.60 ::-.': 74.7 ':? 100:3.04 411.44 1451 · 42 448.38 1 ':.)2'2 77 471 o.% · . m · 2:':: 5 :-?. 4 :_:: 4 ::: 6.71 2'7 6 0.9 2 4 01. 4 5 :31 10, 8 0 2:4 9. :3 7 :'2:4 8 4.2 4 :3'7:3.4 ~''' .,.ol THE C:ALC:LILATIC~N F'ROCEDURES ARE BASED ON 1-FIE USE OF 'I"HRE:E DIME:NSIC~NAi... RADII_IS OF CLIRVATLIRE METHOD. ARCO ALASKA I-...UF ARI_ i.., ALAS;i<A I NC. MEASURED I ° [EFTH ':':;I:::'I!"RF;tY ..... !!!;I .IN WI'FI. I ':::;I IF;:VI<Y TI NG CAMI:':'ANY ANCt...tORA(':~E ALA'.::;KA 'I"RUE V E:: R T :[ C A L V E R T I C A L R [ii C'T A N t'.!; U I.._ A R D E F"F I--I Fi E F' T H Iq 0 R T H / '.'_-:; 0 I_1T H 15'~ ................................ '.::5 ~F/ :35'~ 45? /_-,,/_-, 2 7/:'"~' DATE OF .=&RVEY' FEBRLIARY 16,-1987 CF)MF'L.ITAT!(:IN DATE FEBRUAF;tY 17., 1787 .... lOB NLIMBER AK-BCI-7(::,c)I'? KEL. LY BIJS;HINL'.~ EL_EV. := 5';~;"~"'~i'--~'::l:': C~PIERA'I'AR-ML: L]I_I i RE INTERPOI_ATED VALLIE.':':i; FFiR EVEN 100 FEET FiF L:;LtB-L=.;EA DEF'TH . ........... '~;uBi:'"];~ A "1' L'TI"FA I.... ,::::,:,,::, D V r.., YE.-: R T :[ L. E-:A'.3 ]" / WE~. S'I" D I F'FE:F;:ENC:E CEIRRE":CT I ON ....................................................................... , ..... O. 00 - '='._, '-.~. 00 5'.:.;'. 00 0. C) 0 ._l ::1 , . - . 1 '='''' 0 C) 1 (')('). 0 '25'.-::'. 00 200. () 0 .... "::'"- (')C) 30C) (') ..:) ....I ;:2 · .. · _ 4. 5'.-::'. 00 .................. 400 ."0'0 .... "' 55'?. ()0 500. O0 65'P. 00 c. 0 C). 00 75'?. ()0 700.00 C). C) C) O. C) O c). 00 0.0:3 N 0.02 W 0.00 0.00 ().:30 N 0.2C) W C).00 0.0(:) 0.6:E: N 0.5'F~ W O. OC) 0.()0 C).'76 N :[.61 W 0.01 (:).C)1 0.0'? N 6.60 W ().16 - .......................... 0,"i5 ~ 2. 12 S ~8.65 W 0.94 0.78 7.18 S :38.40 W :3.03 2.10 ......... 16.20 S 6:3.89 W 6.64 :3.61 28.77 :F; ?:2.81 W J. 1.79 5.1U 42. ~7 S 1:30.5'? N ~?.20 7.4-1 ................................ ~/-. 74 ':' 175 70 W -?o 92 1(') 72 . -- · ._, , ~.. , . . . , . 74.75 S 2:3(:). 04 W 45. 15 15.2:..3 'P:3.67 S '2'P1.24 W 6:'3.92 18.76 ............ 115. I6 '.E; :354.44 W 84. 16 20.:24 I42.:31 S 421.84 W 107.7'P 2:3.6:3 1 '76.26 S 4'P 6.01 W 1:36.88 '2'P. 0 :~: . · 217.87 S 573. O1 W 169.81 :32.'?:3 26'?.27 S 650.79 W 206.55 3~.74 97:3 959. lO.':-iEi ........ 105'F'. 00 ,'_--:C.) O. 00 00 ? C)0.00 0c) ..... 1000. O0 () 0 1100.0C.) 00 1200. O0 00 1 ::-: 0 (:). 00 00 :1. 4(:)(_-). 0(:) 00 1500.00 00 1700.00 ARL. c ALA.:.KA KUPARUK ALASKA MEA.=,L KED i ' I: EF TH 2112 '226,'~ 2428 .................... :': 590 291 ?¢ ._-,(. ,_-, ._-i :324:.-? ....... '.:~i~,-'i-s, ._, ._ ,.., ............... :3¥6C) .~, ...._, ._., 410,o 446:3 · 46;48 ..................... 483'4 5019 ._ ..' 10 I N C. 'F;F:'F'RF;,'Y-::? I. IIq 1,4E:I. t A N C H FI R A G E A L A S K A C 0 M P U T A T I 0 N D A T E F' EBFi:LIA RY 1 '.::;', 1 'F.'8'7 "I ~ '-'! i" LRTE OF .=,_RVEY FEBRLIARY 16 ,_lOB I',It_IMBEF( AK-'B'O-7001'.:/ KELLY BU:.-];HI NG E-:LEV. = ...... g':~'-:"i.~'ii;'--F-T-: .............. OF'ERATC~R-MCGLI I RE: 't"R I_1E :.:31..lB- L:; E a T 0 TA [ VERT I CAL VERT I _.t-iL RE(::TANGI_ILAR L:OORD I NATES MD-TVD VERT I F:AI_ I::~E:PTH DEF'TFI NORTH/SOUTH EAST/WEST D I FFERENCE C:C~RREC:T I ON I :-75:~. O0 1 ?00. O0 40'::_-'. O0 t:; :2' 05'?. 00 200 (). 00 4 '76.2 :.'3 :.--_; ,:: 1 f";'-.-,' () 0 2100.00 % =: . "" ........ ,1 :T/C) S ..-.~:._, .-.~. ()0 2200. O0 628.04 '.-_-; · -,--,='o ...... ?._ · -:.: .... .~ O0 2:--:00, O0 702 - 2459.00 2400. O0 776. :3:3 .'.--.; · -,~. ,'~ ,~!. . . .~_ ..... .~-_ ...... :. C)('> '?F,O ('). O0 8.=, 1.24 '._--.; .. · ", · I'-,',"] ,, · . · · -' c-,.::, :. 00 :.2600 ~') 0 '? :27 04 '.E; 27' 5'.:.~. () C) 2700.00 J. 002. :34. S 2 35':..?. (':) 0 2 L--:O0.00 :[ 077.0'7 ~.:.--.; ....................... '2'.:.)5'?. CIO 2:7/00. OC) 1151.55 S :305 '.:). C)0 300 (). 00 1 .,::'-' ~-'-' '"-.::,. 72 S :31 :": 9. (')0 :3100.00 1. 2'.:, TY. 4 () :_:; :'-::':.:' :::~':.'.;. 00 ..... :3200'. 00 " :[ :7', 74.46 :::; '"-"-' 5':? .......... .-.,.- ..... ,F':, (') :'-'::::0 0 C) O .1. 4. :3 4 5'?. 0 0 :3 4 0 0.0 0 15:31,21 S .- ......... :.'. ~...~(.~ :_--:500. O0 1615.56 .'.:.; '2_ 5'? O0 .... · -./- ..... :3600 O0 1702 :::ti :--; 740. '.:25 W 253. :E:2 47. 27 G::2:6.51 W :2:10.2 6 5 ./:,. 44 '--., :'3:5.3 <':, W :.'36'F,. 2'7 5'P. 01 10:3':?. 0 :.--: W 4:31. '.:~ 7 6:;;:.'. 70 1144.7:3 W 4':? 6. :21 64.2:3 1250.82 W 560. '~'-' (..- 63.81 1 :_--:5::.:. 16 W 624. 16 64. 15 1468.5'.:~ W /:.,'.:~0. ?0 66.7'4 1 !581. t.? 7 W 760. 02 6,'.:~. 1:2 :! 6 '.:' 6.7 :.:.': W ::: :,..::'.-./. 88 6, 9, :37' t 8 .1. 4. :30 W '.:.>01, :3:.::71.45 .t'P::',4. :.:.:5 W 974.76, 7.'_:,', 4:.:: 205'7.24 W 104.'?, :::6 74.6 () 2181.08 W .1124.76 7.5.4.0 ................... :2:':':cr:.~_. · '?'7 W 1204 . :3::.:: 7? · =-"._, / :,:.?/444 9/-, W 1 ":":":; " ~)._, :.:::4 71 · . -- .,;.. ,.., ... ,, . · . 2!~,::30 ,-,= /.., ...... :,...., W 1:37 ~, 80 :36. "¥' ..................... '.::.' 7 :l ~, J 1 N :i 46, O, 4.'_--: '" ,_,4.6:_:: 2:34:3 "= 0._, W 1551 1'--' 90 70 ARCu ALASKA, I<LIF'ARLIK ............................... ALASKA D[PTH I Iq C:. , . "-; I: :' I"'i R I::( Y SI.. IN i41":l I. ::";I.II'(VF: ANCHORAGF AI_A'.SKA E:OMF'U]"ATION DATE F'EBRLIAFiY 19: 1'=T/87 C!MI'"'(~IqY ................................................ ............................ '! :': F;', :-':i: ':'~ '-" DATE OF SLIRVEY FEBRUARY :. ._lOB NUMBER AK-BO-TC)019 KELLY BUSHING EL. EV. '= 0 F' E Fi A T 0 R- FI C G U I R E INTERPOLATE[I VAI.._LIES FOR EVEN iC, C) FEET OF .=,I..B-.:,EA DEPTH 'T'R LIE ................................ S LIB-S E A '- VERT I C:AL VERT I CAI_ DEF']"H ........ [~EpTH 54(3.1. :'=':75'::-/. O0 :3700.00 "--, F;':~ 1 '""'"' = ";' O 0 :3 80 O () 0 · -- .-- .. .-~ C ! '; . . .................. 578 (~) ":: 9'::.;"~ (::, 0 ...... !=:'P 00',' 00 " ............. 5':.-.'6/:. 40.5':".:'. 00 4()0C~,. OC) ....................... 1 $ c, 4 ]. 59.00 4100. (')0 42 59.00 ............. '4.20'G.'00 4 :::59.00 4300. 0 C) 4 4- 59. C:,C.) 4 40 0.0 0 '-'-~55'P ,. ,.':~0"45C)C). O0 4 ,."-., 5 ?. (),:'-) 4- 600. 00 4 ""/.~',v"' .... c)C) 4700 (')0 4E:5'=:;'. C:O .............. '4;:::eX-)' '(fir) '- 5400. C) 0 5500.00 T 0 T A L... REC: TAI',IGI_II_ A F,: C:OORD I NATES NCHRTH/.SC~I...ITH EAST/WES]" MD.- TVD VER'T I D I F F: E Fi E 1'4 C E C: C[ R R E C: T I 0 ht '3:~:40'~'23 "S ...... 4832."06' W · .:,4..:,._ 83 ._~ 49 t 1 :--:7 W 1642. :34 91.72 ] 732.7:]: 89.89 18:2:1.. :3/-, ' ......................... i.-'-:i3', ..... ' .. ,'=, .:) ]. '.? 07.57 8/_-,, 2 :I 1 'P --: 9. '.;' 4 :32. :37 2070.65 80.71 :2148. ':7~6 78. :32 ;"..ir 225.6 c.) 76.6, 3 ........................ 2:30 O. t 6, 74. !57 :2442 · 6, .1. 69.8':.'~ .. 25:10. 'P:3 68. :32 '-"=' '-' 67 4:3 J::..J 7 ',--' · '-' r= · ~ .J ,. 2642: · :2:4 64 · 98 '270 ?. 0'? ./:, 5.75 2'773.70 /:,4.6~ 2:--:37.07 63. :37 2898 · 8,'_=: 61.81 2?58.60 59.72 632:-.-.' 6._,07 A ::R .=i,-.-,, 70:31 ............... 7201' 75:37 7702 78&8 80::-:2 ................................................ 8196 8517 ARCO ALASKA) KUF'AF;tLIK ALASKA I NC:. CIT. ff.IF'LITAT I ON [IA]"E F' E:_' B F;,' 1_.1A R V :1. ':;..., 1 ':.-/8 '7 INTERF'OLATED VALLIES FOR EVEN lOC) "I"R I...I Ei; ...................... S LI B-SE A ' T 0 ]' A l... MEASURED VERT I C:AL VERT I C:AL REC:TANGI..II....AR ...................................................................... DEPTH [~E: F"i"I-.-I DEPTH NORTFI/SOLITH DATE OF SURVEY FEBRLIARY 16, 1987 dOB NLIMBER AK--F.:a2~-7()OI'P KEI_LY BUSHING ELEV. = F~F'ERATC~R-MC:F~LI I RE _ 1 FE.'ET hi:' SI_lB-SEA £EFTH C: 00 R D I I',.l A T E E; E A S 'T' / W E :.:.; T ,:,,:, 1 ............... .=i, 5759 ¢':, 0 .=i, 7 (')O. 0 C) ..:,'-' =-,_., '-'~. '-.,~. L:.: J. S =- ,'" ...... '::' ":/.: . :_:.: 4 t,4 ............... ';~';SFW- ............... ..:,'"" c,-' "'" ":~.::, :. ("~n ............. 5:EO0',' 00' :':: ,.'-, A /.., :::",E; '.i:; 51:2i',:3. '71. W ...................... 9102. ,=-c,,.: ,:¢._ .-..._, .: . ('~q..... 5900.00 :_::727 · ("~:::... ._,':' .~t,:.:' 1 '-)..... .8/':, W .......... ... c,, .? .~i /-, ' ' ~:'':'- / ,:,._, · S ::~..~ ~.-, 0 _, .-.~. 0 o E, 000.00 :}.': - '-'"- 97 f~ :':: '4 (9. '"' ~'-' I,,,I ................. 94 i"E: ............ 6:1, 5':::'. O0 ..... 61-00 O0 .... :5:844.4:7..' ::i; 54:?.5..10 1,.0 ~'~ 17.;! ~--, .'""~ · .'#, 1:.'7 ,-- .. it:.' g..-- £~' .~ ..,,=,.- <:,.~: ..... .:/, ()0 620C). 00 3'90:F:. 07 :iii; .... , ....... 2'7 W 974/_-, (:.' '-'"-'--/.::,.::,.-. .............. ()0 /-,:300 00 :::9/-,F,. 04 E; F;665 :it:_--: W ........... '9;F/~ 1 ...... /_:,45'i;), O0 /.-,4C~0.0() 402,'!:,. !:':::~; ~i'_:: !5 '7 :iii: () . 44 W ']~'-.>'~-~:':-:,SS("~F: ""/- /-, 4 ,-1- '--'¢ 7/-, 4057 J,"-, :::; .... ::".-.' ............. -.: ........................ '7.77 W ...... MD--TVD VERT I C:AL D I FF'ERENCE CORRECT I ON ._, .-.'. 0 0 F T. :}) 011.86 ._Pi ._,':'. 2 3:0 El 6,. 5 2 44.67 :30'P '7.8 6 4 1. :'.'!::.E: :2:14. 3.20 4..5. :}.': 4 :3197 14 ,, -_ .._~, # .... ":'":' =;"'-.' '77 62 /-, ':' ._i ~.-. o.... i :7-.:32:.:3.51 6:3.74 :3:387.6/_-, 64. 16 THE C:ALC:di:]AT .]: ON- F;~iSC-.:~-_~-[][]~E-si'---i'ji]_-iE-""A'' L..~ NEAR' I NTi:-7. RPE, LAT i ,iN BETWEEN THE NEAREST :;i:0 FOOT MD (FROM RADILIS OF CLIRVATLIRE) F'OINTS ARF-:~] ALASKA, 3Q-2 KUF'AF~LIK ALASKA I NC:. MEASURED DEF'TH ,2'! ?.~ -':, .-., 95:32 ......... 9654' Ei: F' [ii' R R Y- S I.. I1,,I W .F..] .. I. A Iq C H (:t R A G E A I._ A :.:} K A C:I.. IR V E Y J N G C 0 FII:"A N Y C:O M F'LI'I' A T I 0 N D A T E FEBRLIARY 19, 1'.:.>87 INTERF'OL. ATEL] VAI._UES FOR SF'ECIAI.. T R LIE S U B-S E A '1" fi ]"A l.. V E R T I C AL VIER T I F:A L R E CT A N GI..IL A R D [!:7 P ]"H D E P TH hlOR T H / :.:.';OI_.ITH ....... F'AGE _!.Q ......... ] ...... [)ATE: OF SLIRVEY F'EBRL~ARY 16, 1987 JOB NL. IMBER AI<-BO--70C~ .1. '.:.) KEI._LY BI_i'.:-;H I NiL} EI_..EV. = ........ 5';~:;'".'"i~j'~i'-¢::i:"'~ OF'ERA'I'OR-MC('.~L,I I RE '.3URVEY F'OINTS C O O R D I Iq A T' E'.E; [i:T A :F; T' / WE'..:i;'T MAF;:I<ER ='- 84 .... ,.:, 14. W 5514.5:4 W · _, ..... :i 4 8 W 5/: ()O. :2::3 W C~.' ~ .--t .-', I~.~ -..,c,.:, ,-'..~ W .... ::,.:, z ,, 77 W TRI...INF':. TOF' KUF'ARUK (:: TRLINC. BASE KUPARLIK C: T (7.1F' K I._i F'A R I_1K A BASE KLIF'ARIJK A SLIRVEY DEPTH F'LUG BACK TD TOTAl_ DEPTH DRILLER STRA'F I GRAF'H I C '.._--:;LIMbtARV DERIVED USING L]II_ DFF']'HS AND '.-':i;F.'ERRY ::-.:;L.IN SLIRVEY DA'i'A MARKER ................... MEASLIREn .OEF'TFI ............. 'I'VD ............. THICKNESL:; NITH REF, TO NELLHE~D BKB BI<B "'"1" ,' ..... "-, ],'=- · .:, JB-.:,EA VERT I CAL ( OR I G I N-.,:...:.c .JFNL 2352FEL ) ............................... SEC: . 17 .T !..;~:.U_. RO.... ~E ....................... -- TRUNF: 1-0t::' I<LIF'ARUK F: '?="-"-' . _. . :: .... _',.,::. 62'2 8 ,, 14. ................... ;/:~ONC!'~ BASE KUF'AR I K 'c ,:753.2 6:22:::i:, 14 TOP KUPAI-]'LII< A 'F'532 622:E:. 1,.!L BASE KUF'ARUK A ?/_',54 6:30;.-]:. 67 F'LUG BACK TD 9772 .6:374.40 TOTAL DEF'TH DR I LLER "P '.;" 9' :_:~ 6'='. ._,~..:~" ,::,'-'. 7/',_ ..................................... 61 ,:':,'.~. 14 ,'.'-, .l 6'?, 14 ,'::, 169. 14 624:3.67 6:.:.: 15.40 644'F/. '76 """"'-'"' 4:::S 5514.84W ..Y., ,"~ C, ._1 ,, :B '.-.-.' :3 C', , :'::SS 5600,33W :..:.:'.-? 74 -~ .~ "- ''~ ''~ ~'Au · .-~ 1 .'.--'.; ..... o~. · .., ~ ~ . ~q.-, . 4057 1 ,'_'-,S ._ ,_..:,7 77W ............................................................ 1) FROM LINEAR E~(TRAPOLATION BELOW DEEF'EST STA]:i~iN'.- ........................ 2) COMF'UTER PREH}RAB1 - SPERRV SUN THREE DIMENSIONAl_ RADIUS OF C:LIRVATURE. DATA CALCULATION AND INTERF'OLATION BV RADIUS OF CLIRVATLIRE DATE OF SURVEY FEBRLIARY 16, 19:_--:7 COMPLITATION DATE FEBRUARY 19'., 1987 ,_IL]B NUMBER AK-BO-70('],19 KEI_LY BI_I'SHING ELEV. = 59.00 FT. SPERRY -SUN 5CRLE :- 1 INCh TO 1000.00 / 1000.0 qRCO qLRSKR. 1NC. 3~ -2 PEBRUA8~ I6. t987 qK-BO-70019 TSUE NSR';H f i T I I T -6000. r',jO -50OC. CO -4000. O0 -30 . O0 . -2000. OO -1000, O0 ,.---"'' .~ O. OO --tOOt. CC --2COC, C' HOR;ZONTflL PROJeCT!ON 0.00 5CRLE :- t ]NCh TO t500. O0 / KdPqRdK 30-2 qK-80-?CO~9 1500. 0 qS["O qLqsK,~, ! 1500.00 ~000. O0 4500.00 6000.00 650'8. '76 9993 7500.00 ~ ~s~o. oo 3o~o, oo VERTICRL ?ROJE CT i ON I 750~ ~ t_,. STATE OF ALASKA ~ ALA,., ; OIL AND GAS CONSERVATION COb., SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: OPeration shutdOwn [] Alter Casing [] Other Stimulate [] Plugging [] Perforate I~ Pull tubing [] CONPLETE 2. Name of Operator ARCO ^] aska.. I nc. 3. Address P.O. Box 100360 Anchora~le~ AK 99510-0360 4. Location of well at surface 2205' FNL, 2352' FEL, 5ec.17, T13N, RgE, UM At top of productive interval 810' FNL, 2587' FEL, $ec.19, T13N, RgE, UM At effective depth 900' FNL, 2755' FEL, Sec.19, T13N, RgE, UM At total depth 982' FNL~ 2910' FEL~ Sec.19~ T13N, RgE~ UM 11. Present well condition summary Total depth: measured 9993 'ND true vertical 6509'TVD 5. Datum elevation (DF or KB) RKB 59' 6. Unit or Property name Kuparuk River Unit Effective depth: measured 9772 'MD true vertical 6374 'TVD 7. Well number 3Q-2 8. Approval number Casing Length Size Conductor 80' 16" Surface 5.246' 9-5/8" Production 9828' 7" 9. APl number 50-- 029-?1 ~RR 10. Pool Kupar9k River 0il Pool. feet Plugs (measured) None feet feet Junk (measured) None feet Feet Cemented Measured depth 1875# Po1 eset 115 'MD 1450 sx'A5 ill & 5283'MD 350 sx Class G 300 sx Class G 9863 'MD True Vertical depth 115'TVD 3697 'TVD 6429 'TVD Perforation depth: measured 9556 ' -9590 'MD true vertical 6243 ' -6264 'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail ~ 9475' Packers and SSSV (type and measured depth) HRP-1-SP pkr ~ 9414' & TRDP-1A-SSA SSSV @ 1795' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Compl etlon Wel 1 Hi story) Daily Report of Well Operations [~ Copies of Logs and Surveys Run [~ Cvro 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 Associ ate Engineer Date~- ~_~-~7 (Dani) SW02/15 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. iAccounting State cost center code Alaska IWell no. 3Q-2 District ICounty or Parish Alaska I North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25512 Auth. or W.O. no. ~Title AFE AK1568 I Completion Nordic #1 API 50-029-21688 Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun J Date Complete J 3/6/87 Iotal number of wells (active or inactive) on this DSt center prior to plugging and I bandonment of this well I our IPrlor status if · W.O. I 0845 hrs. Date and depth as of 8:00 a.m. Complete record for each day reported 3/07/87 3/08/87 7" @ 9863' 9772' PBTD, Prep to rn CA 10.0 ppg NaC1 Accept rig @ 0845 hrs, 3/6/87. ND tbg head. NU & tst ROPE to 3000 psi. RIH w/3½" DP, POOH, LD DP. RU Gearhart, RIH, perf w/5" csg gun, 12 SPF, 120° phasing f/9556'-9590', RD WL. 7" @ 9863' 9772' PBTD, RR 6.8 ppg Diesel RU & rn 288 its, 2-7/8", 6.5# 8RD AB-Mod tbg w/SSSV @ 1795', HRP-1-SP pkr @ 9414', TT @ 9475'. BOPE, NU & tst tree to 5000 psi. 2200 hrs, 3/7/87. Old TD Il New TD I PR Depth Released rig ~ Date Kind of rig 2200 hrs. 3/7/&7 ClaSsifications (oil, gas, etc.) Oil Type completion (single, dual, etc.) Single Tst tbg/ann to 2500 psi. ND Displ well w/diesel. RR @ 9773' PBTD · Rotary Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test IGas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate ITitle Drillin~ Supervisor ARCO Alaska, Inf'"'- Post Office =ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 18, 1987 RETURN TO: ARCO Alaska, Inc. ---Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 5936 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this.transmittal. 2A-12 CET. 3-8-86 6410-7007 · 3F-16 CET 1-13-86 7740-8443 2A-lO CBL 3-20-86 6500-7042 3N-4 CET 3-25-86 6690-7736 3N-3 CET 3-25-86 6587-8016 -----3Q-7 CBL 2-15-87 6698-8908 3Q-6 CBL 2-14-87 7494-9545 3Q-2 CBL '2-15-87 7843-9'752 3Q-5 CBL 2-15-87 7809-9941 3N-5 CET 3-25-86 5590-7456 2T-17 CET 9-5-86 6947-8236 2T-13 CET 9-1-86 6900-7752 2T-10 CET 9-4-86 4700-8118 · Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC Unocal Vault (film) ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichfieldCompany · . ~ STATE Of ALASKA ALAS,.. OIL AND GAS CONSERVATION COMk.._JlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order ~ Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, I~nc ~ .: RKB 60' feet ~.. 3. A~,re~s Box 1 00360 Anchorage, Al< 9951 0-0360 6~ Unit or Pr..operty name · · : uparuk ~lver Unit . '. 4. Location of well at surface 2205' FNL, 2353' FEL, Sec.17, T13N, RgE, UM At top of productive interval 960' FNL, 2212' FWL, Sec.19, T13N, RgE, UM (approx.) At effective depth 773' FNL, 2847' FEL, Sec.19, T1.3N, R9E, UM (approx.) At total depth 849' FNL, 3002' FEL, Sec.19~ T13N~ R9E~ UM (approx.) 11. Present well condition summary Total depth: measured 9993 'MD feet Plugs (measured) true vertical 6513'TVD feet 7. Well number 3Q-2 8. Permit number 87 -4 9. APl number 50_029-21 688 10. Pool Ku'paruk River 0il Pool None Effective depth: measured 9772 't~D true vertical 6375'TVD Casing ~ngth Conductor 80' Surface 5246' Production 9828' Size I 6" - 9-5/8" 7" feet Junk (measured) None feet Cemented 'Measured depth 1875#. Pol eset 115 'MD 1450 sx AS I I I & 5283 'MD 350 sx Class G 300 sx Class G 9863'MD ~ueVerticaldepth 115'TVD 3701'TVD 6432'TVD Perforation depth: measured None true vertical No ne None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) RECEIVED MAR ! 9 1 87 Alaska Oil & Gas Cons. Commission Anchor..~:~3 12.Attachments Well Hi story Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation April, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certi~ Signed Conditions of reval that the foregoing is true and correct to the best of my knowledge ~ ~~y.~ Title Associate Engineer Commission UseOnly (DANI) SA2/012 NOtify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] LoCation clearance~ A.x~proved C.c~y Approved by ¢,¥ )g)~_~ ~ ~m)?m Form'lO-403 Rev {2'-1-~ ............... 'Commissioner by order of the coml~ission Date ~---o~ ~)"C.~? Submit in triplicate 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 Alaska Field Kuparuk River Auth. or W.O, no. AFE AK1568 Doyon 9 ICounty, parish or borough North Slope Borough Lease or Unit ADL 25512 ITitle Drill State Alaska no, 3Q-2 Operator ARCO Alaska, Inc. Spudded or W.O. begun AP1 50-029-21687 IDate 2/4/87 I ARCO W.I. IHour · IPrtor status if a W.O. 1030 hfs Spudded 56.24% Date and depth as of 8:00 a.m. 2/05/87 2/06/87 2/07/87 thru 2/09/87 Complete record for each day reported 16" @ 115' 2241', (2126'), POH Wt. 9.3, PV-11, YP 19, PH 9.0, WL 12.2, So1 7 Accept rig @ 0700 hfs, 2/4/87. NU diverter sys. Spud well @ 1030 hfs, 2/4/87. Drl & surv 12¼" hole to 2241'. 431', 3.0°, S72.6W, 430.95 TVD, 3.76 VS, 1.1TS, 3.75W 795', 16.7°, S67.5W, 788.36 TVD, 66.27 VS, 20.40S, 66.28W 1161', 29.9°, S72.SW, 1124.38 TVD, 204.32 VS, 65.71S, 202.45W 1538', 36.3°, S66.7W, 1440.03 TVD, 401.99 VS, 129.655, 398.06W 2104', 48.4°, S55.1W, 1860.01 TVD, 778.51 VS, 318.61S, 724.92W 16" @ 115' 4891', (2650'), Drlg Wt. 9.2, PV 11, YP 16, PH 9.0, WL 8.4, Sol 7 Drl & surv 12¼" hole to 4891'. 2350' 51.1° S53 4W 2018 96 TVD, 966 20 VS, 428.31S, 877 30W , , . , · · · 3321'~ 53.8°, S56.5W, 2610.56 TVD, 1735.74 VS, 878.53S, 1501.73W 4196', 55.4°, S58.9W, 3115.56 TVD, 2449.85 VS, 1261.37S, 2105.00W 4642', 57.9°, S62.9W, 3360.75 TVD, 2820.90 VS, 1442.56S, 2430.53W 9-5/8" @ 5283' 8601', (3709'), Drlg Wt. 9.3, PV 10, YP 7, PH 9.0, WL 8.8, Sol 7 Drl to 5300', short trip, CBU, POH. RU & rn 132 its, 9-5/8", 36#, J-55 BTC csg w/FS @ 5283', FC @ 5200'. Cmt w/1450 sx AS III & 350 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. ND diverter, NU & tst BOPE to 3000 psi. RIH w/BHA to FC, tst csg to 2000 psi. Conduct formation tst to 12.5 ppg EMWe 4960' 5662' 6542 ' 6983' 7427' 8367 ' Drl & surv 8½" hole to 8601'. , 57.3°, S59.2W, 3531.14TVD, 3088.24 VS, 1572.52S,2665.48W , 58.2°, S56.SW, 3895.08TVD, 3685.47 VS, 1886.87S,3173.97W , 55.8°, S55.1W, 4379.01TVD, 4422.98 VS, 2306.98S,3780.16W s 54.6°, S53.3W, 4630.69TVD, 4784.98 VS, 2518.81S,4073.87W · 53.8°, S48.2W, 4890.41TVD, 5143.73 VS, 2746.66S,4352.74W · 51.7°, S43.7W, 5458.26TVD, 5886.02 VS, 3246.54S,4910.36W RECEIVED Alaska Oil & Gas Cons. Anch0r~.~ The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, Date . Title I Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Iht®rim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ]County or Parish J State Alaska North Slope Borough Field ILease or Unit Kuparuk River I ADL 25512 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 2/10/87 2/11/87 2/12/87 2/13/87 Alaska IWell no. 3q-2 9-5/8" @ 5283' 9348', (747'), POH to PU turbine Wt. 9.3, PV 13, YP 11, PH 9.0, WL 8.4, Sol 7 Navi-Drl & surv 8½" hole to 9348'. 8621', 49.2°, S43.9W, 5619.99 TVD, 6077.63 VS, 3387.90S, 5045.92W 9038', 45.9°, S55.6W, 5906.73 TVD, 6377.14 VS, 3589.02S, 5271.32W 9228', 49.9°, S62.9W, 6034.09 TVD, 6517.73 VS, 3661.04S, 5392.37W 9-5/8" @ 5283' 9886', (538'), Drlg Wt. 10.0, PV 18, YP 11, PH 9.5, WL 4.2, Sol 13 RIH w/turbine, packing off @ 9311'. Wrk pipe to 9186', wt up & cond mud. Rm f/9186'-9344', drl to 9886'. 9560', 52.4°, S65.0W, 6242.33 TVD, 6773.61VS, 3774.57S, 5624.63W 9-5/8" @ 5283' 9993', (107'), Wiper trip Wt. 10.1, PV 18, YP 12, PH 9.5, WL 4.6, Sol 14 Drl to 9993', short trip to 9-5/8" shoe, CBU, POH. OHL, RD Schl. RIH f/wiper trip. RU Schl & rn 7" @ 9863' 9993', (0'), NU tree 10.0 ppg NaC1/NaBr RIH, CUC, POH, LD DP. RU & rn 227 its, 7", J-55 BTC csg w/FS @ 9863' FC @ 9772' Cmt w/100 sx 50/50 Pozz & 200 sx C1 "G" , · · Did not recip pipe. REcEiVED 1 9 1°oB7 Alask~ 0il & Gas CmoS. c0mmissi0~ The above is correct IDate -- For form preparation ~nd distributlo"W~n''' f~ see Procedures Manual Section 10, Drilling, Pages 86 and 87 Title Drilling Supervisor 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. District ICounty or Parish I Alaska Field ~Lease or Unit Kuparuk River Auth. or W.O. no. ~Title I AFE AK1568 Doyon 9 North Slope Borough Accounting cost center code State Alaska ADL 25512 Well no. 3Q-2 Drill AP1 50-029-21687 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 2/14/87 thru 2/17/87 IA.R.Co. W.I. 56.24% I,Date 2/4/87 Complete record for each day reported Iotal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our ~ Prior status If a W.O, I 1030 hrs. 7" @ 9863' 9993' TD, 9772' PBTD, RR 10.0 ppg NaC1/NaBr ND BOPE, NU & tst tree to 3000 psi. RR @ 1200 hfs, 2/13/87. Old TD Released rig 1200 hrs. Classifications (oil, gas, etc.) Oil jNew TD I PB Depth 9993' TD 9772' PBTD IDate ]Kind of rig 2/13/87 Rotat'7 Type completion (single, dual, etc.) S lng le Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data W'~II no. Date Reservoir Producing Interval Oil or gas Test time Production ~)il on iest Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected , -. . The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Alaska, Inc. ~ Post Office Bo,. J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: February 26, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk, ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal # 5925 Transmitted herewith.are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ 3Q-6 OH LIS Tape + Listing 2-2-87 ~3Q-2 OH LIS Tape + Listing 2-2-87 ~--- 3Q-5 OH LIS Tape + Listing 1-26-87 ---- 3M-1 OH LIS Tape + Listing 2-19-87 Receipt Acknowledged: DISTRIBUTION: 011 & Gas Cons. Commission Anchorage Date: D. Wetherell ARCO Alaska, Inc. is a Subsidiary of AllanticRIchlleldCompany ARCO Alaska, Inc. Post Office ,. _x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: February 25, 1987 Transmittal f) 5923 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK ..99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of. this transmittal, . OH Finals: (1 blueline unless otherwise specified) 3Q-2 ~5" FDC Raw 2-11-87 7998-9955 ~' 2" FDC Raw 2-11-87 7998-9955 ~"5" FDC Porosity 2-11-87 7998~9955 ~2" FDC Porosity 2-11-87 7998-9955 ~Cyberlook 2-11-87 9250v9950 "-~2" DIL 2-11-87 5288-9981 ~'--5" DIL 2-11-87 5288-9981 Im 011 & · Commissio _ Receipt Acknowledged: DISTRIBUTION: NSK Drilling Vault (film) Rathmell D & M L. Johnston (vendor pkg) Date: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany January 16, 1987 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 3Q- 2 ARCO Alaska, Inc. Permit No. 87-4 Sur. Loc. 220.5'FNL, 2353'FEL, Sec. 17, T13N, R9E, UM. Btmhole Loc. 1066'FNL, 2056'FWL, Sec. 19, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. I.~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. .'.Catt~~ Chairman of / Alaska Oil and Gas Conservation CoI~ission BY ORDER OF THE COI~4ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA '- ALASKA O,- AND GAS CONSERVATION COI,..,41SSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork Drill~¢' Redrill [~I lb. Type of welI. Exploratory [] StratigraphicTest [_3 Development Oil ~f" Re-Entry Deepen Service [] Developement Gas [] Single Zone,~¢ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10: Field and Pool ARCO Alaska, Inc. RKB 60' , PAD 2;~' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk R~ vet 0i ] Pool P.0. Box 100360 Anchorage~ AK 99510-0~60 ADL 25512 ALK 255~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2205'FNL, 2353'FEL, Sec.17, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 960'FNL, 2212'FWL, Sec.19, T13N, R9E, UM 3Q-2 ~8088-26-27 At total depth 9. Approximate spud date Amount 1066~FNL~ 2056~F~L~ Sec.19~ TI~N~ R9E~ UH 01/20/87 $500~000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(Me and TVD) property line ~-7 1 01 75 2056~¢ Total depth feet 125' ~ surface feet 2560 (6505'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depths50 feet Maximum hole angle 55" Maximum surface 21 8~ psig At total depth (TVD) ~1 86 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 12-1/4" 9-5/8" 36.0~ J-55 BTC 5239' 35' g~ ~274' gR90' 1450 sx AS I I I & HF~'ERW 350 sx Class G blend 8-1/2" 7" 26.0~ J-55 BTC 0141' 34' 34' 10175' 6505' 200 sx Class G(minimum HF-ERW TOC 5(~0' abov~ top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface ~,-:, ,:.,. ~,.. ~ ~ ~ ~ Intermediate Production · .L, ~,~, Liner Perforation depth: measured ~"~ ' ~":"~' ~ .... ;: ~ ::;:~ ~:; true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ DiverterSketch~ Drilling program ~ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements 21. I hereby certj,~at the foregoingjs true and correct to the best of my knowledge ,////-- ~~ ' Regional Drilling Engineer Signed / /~ .~~ ~,~,~~' Title Date~/~/~ ,/- ~'b' / ~- ~ Commission Use Only (JL0) PD/026 Permit Number I API number I Appr~a~ [See cover letter ~ --~ 50--0 ~--~ ,- ~%/ ~ ~'~ 87 for other requirements Conditions of approval Samples required ~ Yes ~No Mud Icg required ~ Yes '~No Hydrogen sulfide ~sures, ~ Ye~ No Directi~n~ survey required ~Yes ~ No Required worki~re~sur~r BCE ~;~ 3~ ~ 5M; d 10M; ~ ~5M Other: ~ /~/ ; ~ Approved by ~ ~/ , k ~~~~ Commissioner by order of the commission Date Form 10-401 Rev. 12-1-85 ' Sub~ cate 5000 2900 2800 2TO0- 2600 2500 2400 2300- i I i i ............. __.200 21 O0 . · : 4O0 · . ! . 1.0 b4oo :' 1 ' ~,2~00 i~.2oo- I .i ! ! g13~ , B/ . i t. . . i -' { ' i DEP,,7' DEP' 0.175; DE . . i.. . t. 5000 2900 2800 2700' 2600 2500 2400 2300' 2200 2100 ! , _i ~ t i , t , ~ , i , ,t , .. . ; I . . i 2-800 [ . i 40o i i0 ~00 _ ! I -.. . COo ! i i f ~2oo. -2~oo. I ! 0 (-3 0 ]3, --I 0 ~I. : ~. ~ .. ~ _ I . / . . ~ _, I , . , ' ' T , ' , ' . .... -I ~n~: ~ , . ~ : .... j , ,, ~, ,- . . ~ /.:..~ .:;.l ..... ~. j ..... . .... ~ ............ r ...... t ~ ~ ~ j ~ ~ ~ i _ . ''' ~ ........ ~'' ~ ~' f' J ~ ~" ' ' ~ ......... ' ~, .......... . ~, ........ ~ ' ~ ', ~ ~ .................. . . I ........ I ~111111 I ~1~ !I~ I . . _ ~ , ~ / ~ ..... J . , - ..... ~-~-t .......... j T~~---~--- '-'~ ~ ~ ~ T r ..... ! ~ ' -m ....... ~ ............. ~ ~ ~ ..... ! ...... ~ , s / · ' : ~ ....... t ....... : ' ~ _ L ~&r~f L$'~ ._ . : - - i I ~~ . . ~ . ~ ........... t ~ - .~.. :. ~. ~ .................... l ...... ~. l · ~ i / .- ~ ............ j ....... t ' , : , i ~ . ~ ..... ~ ...... ~ ......... ~ ..... ~.- i / I , . ..... ~ ...... 4 ~ . -' ~ I ..... ' , ~ I. . i ..... ~ ........ ~ ............ ~ ...... "' ~ ~ ', ~ ~ ' ~ ~ ' j ', 1 ~ ........... I ......... ~ . : ~ ~ . I _ = J~ ' , . _ L ~ __.~ ..... '__~ ' ' ~ I .... ~ ................. t ................. ~ ~- - , ' , ~, ~ , , 1 ~ ............. t ...... . ~-~ ....... ~' - ~ ' ~ ~ '' I .... : . ' I ' j ~ ';'j.'.:~-l-~ -~. - ~"' J '- ~i ' ' ' I ' ' ' [ ' ' / ' ~e~m &~- t ....~ .......... ~ ....... ~- , r ..... :::' j: ;: :-_x ;:-:; I :;.:.. :-::. 1 71:81i" ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 19, 1986 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3Q Pad (Wells 1-16) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/dmr GRU1/44 Enclosure ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany 8 17 16 VICINITY ALL WELLS LOCATED IN SEC. 17, TISN, R9E, UMIAT MERIDIAN. NOT~S: I. ALL COONOHIAT[S AN[ A.S.R, ZON( 4. 2. M.A. DESTMiC[~ ~ AN[ TRUL 3.ELE'dltrlONS AJ~ B.P.M.S.L. 4. REF. FIEI,D BCX]K LN.I~, Pellt ZI-2Z. 5. O. G. ELEVATIONS FROM F. R. 14:LL & ASSOCIATES. 6.HOR,ZONTAL PO4JITION~ BASED ON ~Q CC~~ I ~ L~ ~ ~NTS PEN I. HD & AleOC. 'i.:. [W~III 'Y' ASPs" 'X' 6,02S,675.25 SIS, 959.g2 6,025,867.50 6,025,861.28 6,025,855.29 6,025,849.36 6,025,843.37 6,025,837.44 6,025,831.43 6,025, 813.50 6,025,807.25 6,025,801.31 6,025, 795.53 6,025, T89.31 :6,025, T83.4T 6,025, TTT. 44 6,025, 771.55 515, 984.20 516,008.42 S 16,0~2.55 516,056.99 516,081.28 516,105.64 §16,129.72 516,202.58 516,226.82 516,251.42 516,275.50 516,323.80 51 ~,;544.20 516,:~'/~ .31 LATITUDE [LONGITUDE 7t3° 28'54.?58" 149052. 10.512" 70° 28'54.701' 149eS~O9. T9~'' 70° 28' 54.639" 14g° 52'09.06~" 70° 28' 54.5~0" 149°52'08.376" 70° 28'54.521" 149°52'07.658'' 70° 28' 54.462" 1,4~j~m 52'06.944" 70° 28' 54. 405" 14~ 52' 06.220" 70e 28' 54. 343" 14~ 52' 05.520" 70e 28'54. 165" 14~Je52'03.378'' 70e 28' 54. 103" 14~e 52'02.665" 70° 28' 54.044" 144/°52'01.942" TOe 28' 53.9~'" 14~S2'01.240" TO0 28' 5:5.925" 14~52'00. 521" 7De 28' 53.8~7"' 14ffm 51' 59. 814 70e 28'53.80~" 14~ 51' 59. 087" 'fOe 28' 53.749" il4~51'58. 388" I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED ANO LICENSED TO PRAC- TICE LANO SURVEYING IN TH~ STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY M~ OR UNDER MY SUPERVISION, AND TH&T ALL DIMENSION~ ANO OTHER DETAILS ARE CORRECT AS OF 11/2,/86. · e ee~e~,eeeeeeeeee. ~®eeeeeee · *'. ~eeeee '. JO~N W. TAYLOe .. n~[ i c; A .. d . [ st F.N.L.. I ~,t.F.. F_L.. 2194J' 2:~7T' 17.1 2205' 23~2' 17.1 2211' 2528' 17. I 2217' 2304' IT. 2 2225' 2280' 17.2 2 229' 2255' 223e' 2231' I?.$ 224 I' 2207) 17.4 2259' 21:54' 17.5 2265' 2110' I?.$ 2271' 2085' 2277' 2062' IT~ 2:~o1' 1roes' ~?.s ~)1.? 21.7 21.7 21.8 21.8 22,O 22.O 220 22.0 22.O 21.9 21.g 21.8 21.~ D.S.$Q W LL CONDUCTOR ASSUlLT DqSN BY' AJR [ CH~ IY' JWT DATE, II/tO/N NSK I. I · ~-~- ARCO ALASKA, INC. -.~..~ ~.~' KuP,~r-uk Field, North g;loPe: Al~sk~ ~'~ C 1 e,a r-,a n c e R e P ,:, r. t ( S P h e r- :L c ,~ 1 M o t h ,:, ,.".t ) E 1 '1 i P ~_'. :-'_, ,:1 i m e n ~.~ i ,:, n s. h lOT i n c t u ,:1 e d C a. s i n ~ d i me r', s i ,':, n s NO T i n ,::: I u ,::1 e d P r. o ::-:: i m i ~': '.,-' r. a d i u s i s .... (_)(.). f". e e t J.n ca. lcu'la.~.i,n, n5 i n c ,':~ 1 c ,.J 't ,~ 'b i ,:, n s A '11 ,:J e ~; t h s a. r'. e i r, ~: e e t a. n ,:1 a r'- e r. e .F e r e n ,:: e ,:1 t ,'-, +.: h e R EF' E R Ii!: N CEi: W E L L R K B SteP~ise ver. tica.] depth s. ta~:i,:,r,s r'-un -Fr"om (). t ,:, 5,:] 0 0. a. t i n t e r. v a. ] .s-. ,:, .I:: '."-i: O. ~:: e e Re~:er. ence Sl,:,t Ne. me : .... '2 Re f e p e n c e W e 11 N ~ m e : .... ::ii: f3bJect Wet1 N~mes OLIKTOK F'T ~.1 D ~ t e Revis:i. on No [:' F- e p,.~ F- e ,J BY 0 u r- Re ~: : - 2:2:_ D E-" C -:36 :- 49 :- T ,JONE'.i_:; : - D D 1 .'. [ :-:: 00 -, 00'::i: ] F' 0 ,:") '.'i!: ;.'::, 8. ! A R Eastman ; CALCUI_ATION OF LEAST DISTANC:E BETWEEN WEI_LS P,:,sit.1. on c,r, well 2 MD TVD N::; EW Closest P,:,siti,:,r, c,r', ,~ell Ot_IKTOK F'"r' ~.I. ~? :,~MD~,/,~ ', TVD NS EW D .i. s t a n ,:: c: D i r-e c t ~ Be '1: uCe e r', Be t'cue e r We 1.'1 s We 1 t s 2i]. 07 20. 07 '24- 4. ';:' (::, '.:; 2: 4. 7.04 W 40.07 40.07 244.91' S 24'7.0::: W. /=, 0.07 60.0'7 24. 4.85 '.El; 24. 7. 1:3 W ,z,'-'cJ. 07 80.0'7 244. :2:0 S :24'7. 18 W :34. 7.90 S4.5 15W :347 :::':~ .:, 4..: 15 W :347.89 '~" =; · :,-4 .... 1. 6W 347. :2::i:: :":: 45 1 '7 W '~:00. C)0 100.00 O. OC} N O. 00 E 120.00 120. Cx} 0.00 N 0.00 E :'i:40.00 140.00 0.00 N 0.00 E 160.0() 160.00 0.00 N 0.00 E 180.00 180.00 0.00 N 0.00 E 200.00 2()0. O0 C). OC) N C). O0 E 220.00 220.00 O. OC) N O.C)O E 240.00 240.00 0.00 N 0.00 E 10. 0 . C'} 7 100. (").. 7 24, 4. ., 74 ':'._. ';:_' 47 . .:.. 'z' .~.":' W 120. 17 120. 17 244./=, 4:3 :24'7. :2: 7_, W 140.17 140.17 244..51 S 247 4:3 W 1/=,0. 1 '7 1/=,0. 1 '7 244. :=: 9 :;ii; 24.'7.54 W 180. 17 .~ ',!!!K),. i 7 244..'2/.,_. :=; 2-::4.'7. ,-,'_ 5.~, W 200.17 '200. 17 244. 14 S :247.76 W 220. 4- 1 220.4-() 24:3.98 '..:.i; '7. 47.88 W :240.41 240.40 24:3.8:2 S 248.01 W :34,7.88 S45 17W ::34.'7. :3'7 S 4.5 19 W 34.7.86 S45 20W :34. 7. ,:,'-' '=._., .z,"' ,4. ~'.z, .... ;.~ 2 W ,, , .... :::,':-.J..].~ .,::: :3-'::t.'7 '=:4. ' ..... ':: ."!t,W 347.8:3 S 4-5 25W :2, 4'7. S :L F: 45 2'7 W :34'7.7'!;:' S 45 29 W 2. 60 ' 4. ]. :;:":/=, ('). 4 C) 24-:2:. :.-,:..:T, :E; 24- 8. :1. 4- W 2:=:0.4. 0 2 80.4. C) :24-:3.4'? S.; 24 C:',. :;:-27 W :=:00_ _. 40 :'::0(') ..... . ....,":":.".. 2,--].:E: . :3'2 ':::'._, 24:::=",. 4.('). W 32 o. 81 :3'20.80 24:3. I :':', S 24-:;3.5:3 W :3 4.'7. '7'7 '.::i: 4 5 31 W . .=. 4 ..... ::=: :3 W :2:4'7 '74 '" :34'7. '72: S 4. 5:36 W :34-'7.68 S 4. 5:3:2: W 340. O0 :340. O0 :360.00 :3 60.00 · '=,o(-) (-)(-) :-..:F:O. 00 · _~._.. · ...... 420.02 420.00 440.0:3 44(.]. O0 460.0/=, 460. O0 4:3C). 10 500. 15 520. '---.':3 54o. :3 i 540:~'00" 560.4:3 560, O0 . .6.'.::' ~ W 4 2'7 S: ~, ~, 5. :=::'2-': '.-5; ,' 7. :=::2: W 6.52 '.3 '? 57 W :3 4-0,8:1. :3 4 (), 7'.:.? 2 4. 2,9:3 S 2 4. ::i:, 6 6 W :'::_/-,_ (')_. ',_:: 1 :::', ...../-, 0 . '7 '='... 242 . -z, ._,":' S :24 :ii!'. . ::']: 0 W ...... -""; 242 .. ..... :, .=, .. ........... :'::::', ("), ::~i: 0 :':: ,,z: (") , / .... ~:::' "-, ,-" '::,,'l. :::,, '::~ ":', W 4 00.80 400. '7'.:;' 242. :2::3 '.F; ':.249.0/-, 1,4 4-1 ',E',. 57 41. 8..55 242.22: '.:'.; 249.2:2: W 4:2:8.57 4:33.55 24:2. 1 :.2 ::']; 249.44 W ..... %'"" :24 :;ii: (")2 S ..' 4 .~ /=,5 W · 4 F,:::', ~ 8 4 ..... ::,. 5/= ...... '-' 9 · 47:'-]:. 59 478.5/.-, 241. '::.'2 ::~; 24.9.87 W :=: 4 2.0 7 '.:; 4- 5 48W :34. 0 6 9 .:, 4.-, ~- :3 :=','.;:.'. :'2:0 '.E; 4 5 .,.! 2 W 3:37. '70 :-7..4. 5:3:3W 580.5/=, 580. O0 600.72 600.00 620.91 /=,20. O0 641. 1:3 640. O0 7. :32 S !!·4.9 W 9.25 S 1:3.58 W 10.80 S 15.85 W 12.47 S; 18.:2:0 W · -- . -- . ,_, ,_, '2 51.7 7 W :3:3 i. 7 2: '.:_i;-1-5 2.:: :3 W CALCLILATIr]N OF LEAST BETWEEN WEI_LS D I S T A N C F F:.'.:? t= Pc, sition on well -.."-' MD TVD NS EW Cl,",sest Pc, siti,:,n ,:,n u~el'l OLIKTOK F'T -~1 ::~;~D~ ~.~ ~:~ '¥ V D N S E W D i s t a n c e D i r.e ,'- t ' E':e tuJ'e e r', Be tree ~.,I 661.38 66 C). C) C) 14.2.:'6 S 2.-:C). 93 W 681.66 68C).00 I6. 17 S 2:3.74 W 701.9'? '70C).0C) 18.2.1 S 26.73 W 722.._,._ ':? .~, 72 ...... (') . (')c) '2 c) . :5.: 7 .:,'-' 2_ 9.. 9. 1 W · --, IL':'. -']* ~ /-.4.5 o~ /-,4;q 71 ~.4-.:, :=:C) :=i; ~: .... 1 99 W _ · t_, "T .... - . ... . · 665 9:3 = '-' /. " .... :'~"':' 1 c) W . 66._,. 77 ..:4...-,. 9:3.=, ~ ....-. _ /..,86 o:-: /. o~.-] 84 .-: 4.,::, o 6 '..2; 2 F~ 2 21 W _ . . --' ~.,, .... u . .... '705. :30 7C) 5.08 249. 14 :=; :252.3:2 W 327,4 ':.::: :-2;44 56 W :3':.'.' 4. '.:.';' 6 S44 4:2W :.2: 2..'. 2.2. 9. c:.._, 44. 27 W :319.42 S44 l:2W :7~2.. 76 740 C)C) 22,/' .~, o c,.:, .=.,/. W 76:3.22 7/-,0_.. 00 ~._,.'-'= c)a. _ S :3A_. 80 W 70 .... 72 780... 00. _ ~7.60 ._, ~0 ~'-' 804.27 800.C)0 :30.'27 S 44.44 W '~*= 54 84.0 00 .:,% o,;, ,-. ~2 84 W ~_,~._~. . _ .-~._ . .- .. .Z~ ... · 866.26 860.00 :'39.04 S 57.:32 W '.:.:' 14./=, ]. 91:5.:, ':ii: 4 '.'ii'. 6':-.; ,, '.:-:' 1 ::'.; 25:3, 4-?=; W ? 5:: 4. ? 5 'i.:,':3 :=:. 44 :272, :2'7 '.3 ';:' 5 :iF::./=, 1 W 292., ]. :ti!: :.-'!; 40 55 N 2:!38. :3:3 S 4-0 25N ':.!: :34.24. S :'3'ii:' fi:'; C) W 2 7'ii," · E: 1 S :2: 5:' 10 W 992.::. . . C)2. ':78C). . . (")c) .... /-,C) . 17 S ,_,'::"::',_,. :::/",_ _ W 1013. :=..' 5 1000. C) 0 64. 1 :.2: 5] '? 4.2:7.: W 1 C):3 4.5 6, 1 C) 2 0.0 C) 6,:.2:. :3 2. '.B 10 0. :3 2: W 1('). =',. '=,. '?'7 1 C) 4c). c)(:) 72 . ,_,L 1 .=,"" 1 C)./-,_. /-,_ ":'.,:. 14 ].077.46 1060.00 10'? 9. 0 6, 1080.00 1120.75 1100.00 1142.55 1 (20. O0 1164.46 1 1186.49 11 , 12oe. 1 leO' '' 12:3(."). 9C) 1:200. O0 1253.30 122C).00 1275· 84 1240.0C) 12~/8.51 126C).00 1321.34 12:30.00 77.05 F'-; 11:2:. i :}'.: W :31.6:3 S 11'P.:36 W ,_,°/__.. 5:_ 6 S ! 2/-,_. :.2:1 W ':-..' 1.25 S 15::'::. '?:.2: W :'76.28: S 14]..:38 W .1. 06:3.'=: S i .~/-, ':'/-, H ,, . 112. :34 S 164. '=.-.'6 W 955. :2:1 '.:.:'5:.=.:. 6,,"_-, 2'74.6:3 F:; 25:.2:. '76 W 975. ,'.'=,8 97:3. :=:'.:::' 27,'::,. ,:7,:,p :--_:-; 25:3, 92 W 996.08 5?'.:.) 4. 15 27 ?. :.2:5 '.E; 25'P. 0 :'_=:: W 1 (-) 12 ':':'":' 1 (")1 c) ::::/-, '2:-2:1 .=,:5.: :.=.; '-'-=' ''"' 07 W . · .- -.J . - - - -- - .... ~'--' '-..~ ::' ** 5:3./=,7 ].051. 15 2:37.50 S 258.59 W 1C)74.07 1071 . :32 ':-?.':;':")... _. 4-':,'.. '.E; .,..._'",.=i,o,_,. :::5_ W 0':T.'4.4'=7.' 10'P 1,51 25;':]i:. 4-:=: :":; 258. 11 W · 05.30 1102.21 2':..".~"]. 0,':-, ':=: 25~:' ':)9 W 2 :=:. '78 11:20.32 '--.."i.=-':'--:. 70 S ~. 01 W 44.45 :! 140.5"7-' 302.74:, S 25'8.04 W /' = '-'.=,~' 06 W ,: ..... 16 t 1,6, 0.85-" 306.03 S ~._ ,-.. . 275. 1 :E: :E; :2::.'3 2: El: W 2-70. :2:5 5=;:2:7 44 W 265. :2: 4. :.2; 3 6, :2;7 W '17-'/-, C) '"' ' ....... = .:=, '.i3:5: 4:, 7 Lq 2:58.0'=? W 214.24- S 2 :'-': 4- 4 :25::2:. I i W :20':;'. :5.::]: :5.;21 .4-6, t/, 2-::58.5:3 W 205, '24 '.-31 S;' 5:7-:: C':ALCLII_ATION OF LEAST DISTANCE BE:TWEEN WEL. LS P,:, s i t i ,:, r, ,:, r, uJ e 1 1 :;3 M D T V D N :55; E W ., MD T V r) N S E W B G: '1:.' bJ ~ ::? 1"~ .}}: E: '1.' kd <'-'_' '8 r We'l.ls Wel ts · .:,4 4. 1 71. :30 O. 0 ("~ 1 4 ;7..!: 4:3 :'.-'5; :;:'0 9 :1. 4 W ...t _ _ . _ . ~, :.5:67.45 1320.0() 148.98 S 21:i3.75 W <, .-.~ t). 7 571. 3 4 0. Q(") .1. =' r.,..,- '71 ::i; 5:: 2 8 /.'., 4 W 4 14..=..., '~' ":' 1 9, ...../', ("~ . Q () 1 A_ 2 .6 :'::_ .:,'- ..... ~"-'.:,,::, ''~' . 8 C}. N 1 437.88 1 :'-':::::0. o0 1 6':?. 74 ::, ,:4 .: 24 W ....... ' ...... ":--":~ 97 1461 7:3 14-00 oO 177 O~ .:, ~_,,:. W 1 48.~_, 77 1 420.. C)¢)_ _ 1. t7.44 . .=;/_-,_ ':'._, :7'7_..1. .00_ W 1 5 1 0.0 2 t 4-40. c)() 1 '.:.:'2.2 8S 2::-::2. :55::3 W 1534.49 1460.00 1559. 18 14:55:(). 0 () 15:::4. I .1. 1500.0 ("~ 1 6(")9.2:3 1 5 20. o () 2 0:3 "-" 7 '"" :'::(~) Fi ':.? ~l W .... · ...,. .'% ...... . 2 1 6.7 4 '.'55; :3 .1. 8, 2.-':5 W 212.=; ":'~ '-' . ...... .......... ::, 9,5:Q 85? 1,4 1 :.5:4 0.7 0 1 :}.'::]:: .1.. :5 4. :55:4 7. :[ 0 2 6 Zl. 2 3 W 1:2,6,2 5'7 1 "::'~ '? 6, 2- .... ':'-"" '7 4'S '-" =:' ,5 / ..........._,._ ~ ..., , ... ::,,.:,...,. . .... ~,,I. 1:3 8 4.5 1 1:55:7:55:. 7'7 :":: 5 8. zt 0'.:.!; 2. <'::, 7. 1 2 W .1. 4. 0 5.3 () 1:3 9 3. :55: i :7:6 :;ii:. "7'5. S 2 6:3.4. 9 W 1 4 4 6 ,, :!:: 2 1 4:5: :3, 4 '7 :3'7 5, 5 1 'S . :2'7 2. ()() W .I. 4 (:, 9. :3 4 1. 4 5 4. '.::.:' :iii: :55', :31, ::?,'i::' :.:..]; :2'7 ::.::: ,, 5;' .1. W 1 4 9 1.5:' 5 ! 4 7 6. !:5:3 :55::!3 :![::. 2'.:.:' '.3 2 7 5. :55::.2 kt 18 4.. 4.'7 '.[.-; 4. 5 OW :L82,05 S .1. 52W 1. '7'.:.:'. 5:'ii'. '.E; 1 1 '7 E 1.'7',3. 12 :55; 4:1::"':' ..... 1 6:--:4.7 2 1 5 4 0.0 () 1 6 6,0.4.:3 .1..~ 6 o. 0 0 1686.42 15:.3(). 0() 1712.72 1600.00 1:!:::0. !6 S25 55E ! 8 2.4 9 S 2 5:' :':.-: <'::, E .I. :35, 5 5 S 3:3 .1. F:E t 5:.':iii:. !f:'; 0 :iii; 4 () '2 6 IE 1. S:' ::::: ,, ,:::, t. S 4 zt 6, E: 2 0/!.. 6 !?:; 'S 4 7 4:31E 1 .:.4 .-.. :55::3 1 700 00 1877. :3:2 1 '720. O0 1906.75 1740.00 19:_--:,6. 15 1 ~,60. O0 ?66. o6 .l '?'F, 6.5 t 1 2027.54 1820.00 2059. 18 1840.00 ::3:1. 4-. 61 5:; 4/:., !. 9 5 W .1. 7 <.:;'7. 'P ::3 16, 8:7: ,, 2 U 4 4'7.0'2 ::5; 5:."? 7.6 7 W ':'":'/- Q::', '..-'5; 4'.7:'-:', 72 L4 .t.}":31 -7,::, 1'7Q/., :;:5:::-"_.' 'q- !:5 :::}: ':-)1 ::.:.; :'::(')C) 1/-, · --'.' ,._~m - _ ~ .. , : .' .... - ,~ ....... - 3:7.:7. :30 '..:.:; 4.'.:.:'6, O0W i-7!55.7'.:..' ]. '7'5::".::', :'_:: 1 4. L5'.--.:. ,'."~:'::', S:7{:02.. 66 I,-,,I :3 4'.:?. 9:5::']; 5 1 :'"':. 8 :;.2 !4 1 '7'7'::. 'P 4-1 '7 :!5'2.5 5 4. 6 !:5. '::::"F: ti:; :3 0 5 · 1 7 W :'.:':/:,'-2.4 5 S .':5:7:: 2. :2 ('-* W. :':-:'7 ?;. :37 :.7.; .,.,55 1. 1 7 W ::::E::::. '72 S 570. 77 W 4-0 2.5 :':: '.:; .':,'.:--' .1.. 0 4 W 2 4 '.:..". -'.'-! '7 :-::; 4., 4. !::' E: 2,'.'_-, J.. F.; ,'!, 9 6, 7 :;:." E-: '::2'7 4.. '7 5 ::; <::, ,::? x! :5:15::: 2 :.2: 5?. O,'L-, :-':; 7 2 2 !5 !E 2091.49 18/_-,0.00 2124.53 1880.00 2158.7:5 1900.00 21~2.97 1920.00 4.16,. 81 :.--.; 6,12.0 2 W :[ 9 05:. 7 8 1 :'-:'71.72: 4.'7..','_':,. i ::5: .5:; 4 :.5:1.6,1 S 6:3 :.5::. '75 W 19 2'?. 4,5, 1:55:'? 6,. 4-:3 ."5 C:, :,:2.5'P :-2; . ' = . .......... 0 7. ,:'-.~':;2:5; 44/:, 96, '.:; ~:,._,,5, '---29 W .1. 95,!. 99 1 '-? 2 <") '.:.:",:::: ':' ""'" 4/-,2 87 S 679. "= W .. · ¢"~._! .. _ . · ..... B ti!i:-f'W E [ii: N W E:I... !.... ~iii; M D T V D N S l:ii: W *' ;t .~, .~..z~:7.78 .1. 'ii:,Zl.O ,, ()0 :2:262, 6C) 1 '? 60,00 2 2 9 7.4 2 .1. 9:30. 0 () 9.-~.:-,..-., :2 42 0 () (") (') .,_.., ._l j.. n . . n _ ... ....... , .... :'~ ) :,.::',, '7 ::3 1 ?'i;)6 / .,::'. . 511.00 ?:; '75 O. :32 W 2 ("} 5 ?.:'. 7 ! :;ii: 02 !. 62 5 :]:i 5.5"7 '.-]; 3 :iii: 5.25 W ."::;'::'7 04 S '77:3 ::T'::7 W .... '"' '-"= /-, ,: ~ ),-,., :3:2046. ": 2 !:::; 42 1:3 ?; :3:3::3 '.I. :3 W .,::..:, :,7. '2(')7'C). (2 ._, ............ 2 4 01.8 7 :;ii:() 4 (). 0 0 ...... :-'. 1:3 :.::; 8 2(), '!t:,8 W 21 t. 4.0 :'":': 2 0'7 :}: ,, 7 8 214 () ,, 14 2 ~'-)9 8 ,, '7 :3'2'7 ,, 5 &, ?.; 8 5 /..t. E 4 ! 7 ,, :ii::'7 :![!; :E: ,'.":, :3'7' E 4:3 :i!!', ,, ,.".t-',iii: S :i.:.', :iii: 0 E r /-/-7 Eastman KUPARUK RIVER UNIT 20' DIVERTER SCHEHATIC I DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WI[LD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH T~/O 2-1 / 16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLIN~ SPOOL W/lO" OUTLETS 5. 1 O" HCR BALL VALVES W/10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOFIATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REHOTELY CONTROLLED TO ACHIEVE DOWNWI~ DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, I1~,., REQUESTS API::~OVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROH 20AAC25.035(b) MAINTENANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. D,O NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES 11-3-86 · I 7 , 6 > > DIAGRAM #1 13-5/8" 5000 PSI RSRRA. BOP STAC}< 1. 16' - 213OO PSI TA{q<CO STARTING HEAD 2, II" - 3(3(30 PSI CASING kE. AD 3, I1' -3000 PSI X 13--5/8' - 5000 PSI SPACER SPOCL 4. {3--5/8' - 5000 PSI PIPE R/~ 5, 13-5/8' - 5000 PSI DRILLINO SPOCL W/CHQ<E AN3 KILL LIhES 6. 13,.5/8= - ,5(X~ PSI DQJBL~ RAH WYPIPE RN~ ~ TCP, AC(~TOR CAPACITY TEST 5 4 13--5/t~' B(~ STACI( TEST I. FILL .BOa STA(]( AN3 ~ MN~IF~ WITH ARCTIC DIESEL. 2. CHECI( THAT ALL LOC{( ~ SC~ IN ~ ARE FULLY RL='rRAcg~. SEAT TEST PLUG IN WELL~ WITH Rt~I~ JT AI~ RtN IN LOQ~ SC~. LIhl[ VALVES AD~ TO I~ 8TN](. ALL ~ 4. PI~ UP TO 250 PSI AI~ HOLD FOR I0 MII~ IN- CREASE PRE~ TO 3(300 PSI AM) HOLD FOR I0 MIN. _;~ m~n p;~ TO 0 PSI. LIhE VALVF_~. CLOSE TOP PIPE RAMB ~ HC~ VALVES ON KILL AhD CHQ<E Libra. 6.TEST TO 250 PSI AhD 3000 PSI AS IN STEP 4. 7. CONTIhIJE TESTING ALL VALVES° LIhr~o AhD (]~ ~rI934 A 250 PSI LOW AhD ~(XX} PSI HIOH. TEST AS IN NOT A FULL Ct_OSlh~3 POBITIVE SEAL Ohl. Y FUI~ION TEST C{~ TI~T DO bDT FULLY CLOSE. 8. CPEN TOP PIPE RAMS AhD Ct.__c~_ BOTTCM PIPE RAMS. TEST BOTTCH PIPE R/MdB TO 250 PSI AI~ 3000 PSI. I0. CLOSE BLIhD RA~ AhD TEST TO 250 PSI AN) 3000 PSI. MANIFOLD AhD LIhr=s ARE FULL CF ~IhlO FLUID. SET ALL VALVES IN DRILLING PO~ITICN. I Z. TEST STAI~IPE VALVE,q, KELLY, KELLY COQ(S° DRILL PIPE SAFETY VALVE, AhD INSIDE ~ TO 250 PSI AhD 3000 PSI. 13. REC~ TEST IhFC~TION (]4 BLCI~ PR~-V~{~2~5~ TEST FORM, SION, AhD SEhD TO DRILLINO SL~I~CR. 14. PERFC{4M (~ BC~ TEST AFTER NIPPLINO UP AhD WEEKLY THE]~=Jk="TE~ FUI~ICNALLY C~TE B(~ DAILY. I $10084001 REV. 2 MAY 15, 1985 · m Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pR 9-10 9.5-10.5 9.5-10.5 Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit°Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. LWK5 / ih In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xm~s tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standi~. 17. ~erforate and run completion assembly, set and test packer. 18. Nipple down blov out preventer and install Xmas tree. 19. Change over to diesel, 20. Flow well to tanks. Shut in. - 21. Secure well and release rig. 22. Fracture stimulate. HUD ' L SHALE ~ ST I ST L~K4/ih TYPICAL HUD SYSTEH SCHEHATIC · ! CHECK LIST FOR NEW W~.I, PERMITS ITEM APPROVE DATE (1) Fee 1. (2) Loc (2 thru 8) (9 thru 13)r ~ 10. (10 and 13) 12. 13. (4) Casg ~v~.~ /-rd-~7 (14 thru 22) 14. 15. 16. 17. 18. 19. 20. 21. 22. (5) BOPE (6) OTHER (6) Add: (23 thru 28) (29 thru 31) Company--.o?_/t_Co ~'c~ ,~,,~-~. ¢,.. Lease & Well No. "' ~ ' YES NO Is the permit fee attached .......................................... ~ 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................. 5. Is sufficient undedicated acreage available in this pool ......... 6. Is well to be deviated and is wellbore plat included ....... , ....... 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... ~ ,, Is administrative approval needed ................................... Is the lease number appropriate ' Does tbm well have a unique name and number ......................... W..~ Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety'in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandommnt procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. For 29. 30. 31. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equi _p~e____nt adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to 3 ~gp psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32 Additional requirements ' Geo logy: Engineerir~: rev: 07/18/86 6.011 UNIT ON/OFF 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 APPENDIX. No special effort has been made to chronologically organize this category of information. LIS TAPE VERIFICATION LISTING LVP OlO,H02 VERIFICATION LISTING PAGE I HEADER CONTINUATION ~ :01 PREVIOUS REE~L : COMMENTS .LIBRARY TAPE · TAPE HEAOER ~ · , .EDIT ORIGIN :721~ TAPENAME CONTINUATION ~ :01 PREVIOUS TAPE : COMMENTS .LIBRARY TAPE ~ FILE HEADER FILE NAME :EDIT SERVICE N~ME : VERSION # : DATE : MAXIMUM LENGTH FILE TYPE PREVIOUS FILE ~--~ INFORMATION .001 : 1024 RECORDS '~'~ MNEM CONTENTS UNIT TYPE CATE SIZE CODE CN : ARCO ALASKA, INC. 000 000 018 065 WN : 3Q-2 000 000 004 065 FN : KUPARUK 000 000 008 065 RANG: gE 000 000 002 0~5 TOWN: 13N 000 000 00~ 065 SECT: 17 000 000 002 065 COUN: NORTH SLOPE 000 000 012 065 STAT: ALASKA 000 000 006 065 CTRY: USA 000 000 003 065 MNEM CONTENTS UNIT TYPE CATE SIZE CODE PRES: E 000 000 001 065 ~'~ COMMENTS ~ LVP OlO.HO2 VERIFICATION LISTING PAG~ 2 SCHLUMBERGER COMPANY ALASKA INC WELL STATE = ALASKA JOB NUMBER AT AKCC: 72196 RLIN #1~ DATE LOGGED: Ii-FEB--8? LDP: RICK KRUWELL " ~ 52 ' CASING = 9.625 '" ~' 83 : ~.5 C3 BIT SIZE = 8°5" TO 9993' RM RMC = 3.15' ~ 72 D RM AT BMT = 1.56 @ 143 M~TRIX SANDSTONE ~)-~*** THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVER'LAYS FIELD :PRINTS LVP 010oH02 VERIFICATION LISTING PAGE 3 ,"~ SCHLUMB.ERGE'R LOGS INCLUDED WITH THIS MAGNETIC TAPE: · DUAL INDUC'TIONi SPHERICALLY LOG: (OIL) DENSITY~DATA AVAILABLE: 9955' TD 7995° COMPENSATED NE:UTRON'LOG (FDN') NEUT ON DATA AVAILABLE~ 9940° TO 995' GAMMARAY' IN CASING (GR°CSG) DATA AVAILABLE: 5310' TO 80 ~ DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66 0 B 4 73 60 g 4 65 .lin 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API AP1 AP1 AP1 FILE SIZE SPL REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NO. CODE (OCTAL) DEPT FT O0 000 O0 0 0 4 1 68 00000000000000 SFLU OIL OHMM O0 220 O! 0 0 4 1 68 O0000000OO0000 ILO OIL DHMM O0 120 46 0 0 4 1 68 00000000000000 ILM' DIL OHMM O0 120 44 SPOIL O0 010 01 GAPI O0 318 IN O0 28 /C3 O0 350 02 /C3 O0 356 Oi O0 420 0.0 000 FDN FDN CPS O0 330 CPS O0 330 GAPI O0 310 O1 L6 O0 635 2I 0000000~0000000 00000000000000 DATA DEPT SP C A L I RNRA F~C NL 10010.5.000 SFLU -39.1562 GR 9.7344 RHOB 3.9805 NPHI 468.0000 GR DEPT SP CALI RNRA FCNL 10000.0000 SFLU -17.3750 GR 9.7344 RHOB 3.9805 NPHi 468.0000 GR DEPT SP CALI RNRA FCNL 9900.0000 SFLU -25.7813 GR 9.9375 RHOB 3.7813 NPHI 560.5000 GR DEPT SP CALi RNRA FCNL 9800.0000 SFLU -33.3750 GR 9.5469 RHOB 3.4648 NPHI 620.5000 GR DEPT SP CALI RNRA FCNL 9700.0000 SFLU -31.1406 GR 9.7578 RHOB 3.5918 NPHI 593.0000 GR DEPT SP CALi RNRA 9600.0000 SFLU -39.0000 GR 9.3594 RHOB 3.1016 NPHI 3.3843 62.9062 2.1543 2.I484 -999.2500 3°3805 94.5000 2.1035 45.80'O$ -999.2500 3.0691 103.5000 2.4922 40.6250 -999,2500 4.1374 110.1250 2.4961 36.8164 -999.2500 3.2121 97.5625 2.5723 41.1133 -999.2500 t7.6180 70.8125 2.3340 31. 3477 ILO TENS DR HD OPHi TENS 3.1672 ILM 3.1546 I09'5°'0000 GR 62-906,2 0.9668 -999.2500 ILO 3.1636 ILM 3.1536 TENS 3170'0000 GR 94.5000 DRHO 0.0498 NR~T 3.7422 OPHI 33.1269 NCNL 1863.0000 TENS -999.2500 ILO TENS DRHO DP'HI TENS ILO TENS DRHO OPHi TENS ILO TENS DRHO DPHI TENS ILO TENS DRHO DPHI 2.9576 ILM 3.1147 5628.0000 GR 103.5000 0.1509 NRAT 3.4766 9.5734 NCNL 21t0.0000 -999.2~00 3.2316 ILM 3.4459 5544.0000 GR 110.1250 0.1597 NRAT 3.2363 9.3367 NCNL 2150.0000 -999.2500 3.0810 ILM 3.3964 5188.0000 GR 97.5625 0.1353 NRAT 3.4883 4.7207 NCNL 2130.0000 -999.2500 16.7585 ILM 18.1672 4824.0000 GR 70.8125 0.0254 NRAT 2.9004 19.1605 NCNL 2656.0000 LVP OlO.H02 VERIFICATION LISTING PAGE 5 FCNL 856.0000 GR -999.2500 TENS CA LI RNRA FCNL 9500.0000 S LU -35-9687 G~ DRHO D. PMI '435.5000 GR -999.2500 TENS ~PT 94~00.0000 SFLU GR FCNL 424.7500 GR 2.3398 ORHD 48.'9258.. OPHI -999.2500 TENS OEPT sP CALI R:NRA FCNL 93 )0.. 0000 SFLU - :3' 4:375 GR 1 Z.7238 ILO 111.I250 TENS 373.2500 GR -999.2500 TENS DEPT SP CALI RNR~ FCNL 9200.0000 SFLU 4.06g~ ILO -30.8750' GR 113.4375 TENS 2. lZ50 DRHO 49.9'023 OPHI 333. 500.0 GR -999. 2500 TENS DEPT' SP CALI RNRA FCNL 9100.0000 $'FLU 3.67810 ILD -15.3438 GR 3.23.500 TENS 9.7813 RHDB 2.5762 DRHO 3.5098 NPHI 36, 6699 OPHI 870.5000 GR -g99.2500 TENS DEPT SP CALI RNRA FCNL go00.O000 SFLU 3.8500 ILD -20.5000 GR 126.'9375 TENS 11.3203 RHG. B 2.4570 DRHg 3.6211 NPHI 39.0625 DPHI 493.2500 GR -999.2500 TENS DEPT SP CALI RNRA FCNL 8900.0000 SFLU 4.3118 ILD -15.9062 GR 144.6250 TENS 12.0156 RHOB 2.4238 DRHO 3.6816 NPHI 42.3828 OPHI 507.0000 GR -ggg.2500 TENS DEPT SP' CALI RNRA FCNL 8800.0000 SFLU 3.5335 ILD -18.2187 GR 115.3125 TENS 12.8672 RHOB 2.5098 DRHO 3.5391 NPHI 34.1309 DPHI 617.0000 GR -99~.2500 TENS DEPT sP CALI RNRA 8700.0000 SFLU 5.8923 ILO -65.4375 GR 95.1875 TENS 11.0156 RHOB 2.4492 DRHO 3.3887 NPHI 33.0566 DPHI -999.2500 2.9561 I'LM 5.240:, 0000 G:R -999.2500 1.7261 ILM 5164-:.0000. GR -999.2500 2.98'31 ILM 4932-i0000GR -999.2500 3.5227 ILM 5!32-0000 GR 0.0542 NRAT 31.82:50 NCNL -999.2500 0.0215 NRAT 4.4840 NCNL -999.2500 3.5638 ILM 4692.0000 GR 0.0615 NRAT 11.7039 NCNL -999.2500 3.8082 ILM. 4504.0000 GR 0.0444 NRAT 13.7160 NCNL -999.2500 3.5839 ILM 4372.0000 GR 0.0630 NRAT 8.5082 NCNL -999.2500 4.4549 ILM 4620.0000 GR 0.0464 NRAT 12.1773 NCNL 3.2.030 98. 5625 1. 8037 7'75:00 3.8887 ! ' 00:.00 3 .. 0558 11 I'- 12 50 3.5048 1I:3.4375 4.0977 1461.0000 3.2154 323.5000 3.2480 3056.0000 3.6Z13 126.9375 3.4707 1787.0000 3.8488 144.6250 3.6699 1867.000'0 3.6346 115.3125 3.2401 2184.0000 4.9001 95.1875 3.1309 2392.0000 LVP:OIO.H02 VERIFICATION LISTING PAGE 6 FCNL 705.5000 GR 8600.0000 SFLU -69-0625 GR -9'99.2500 'TENS -999.2500 FCNL CALI RNRA FCNL R'N FCNL · CALI RNRA FCNL PT CALi RNR A FC NL DEPT SP CALI RNRA FCNL DEPT SP CALI RNRA FCNL DEPT SP CALI RNRA FCNL OEPT SP CALI RNRA ?05.5000 GR 1~.6953 RHOB '-6406 NPHI 621.00.00 GR 597.5000 RHOB NPHi GR 10.5625 RHOB 3.4082 NPHI 690.0000 GR 8200.0000 SFLU -72.8750 GR 10.8594 RHOB 3.47'46 NPHI 651.0000 GR 8100.0000 SFLU -60.6250 GR 10.9219 RHOB 4.3242 NPHI 506.0000 GR 8000.0000 SFLU -86.1875 GR 9.7109 RHOB 3.3164 NPMI 591.0000 GR 7900.0000 SFLU -87.0625 GR -999.2500 RHOB -999.2500 NPHI -999.2500 GR 7800.0000 SFLU -82.2500 GR -999.2500 RMOB -999.2500 NPHI -999.2500 TENS -999.25'00 TENS 4.2500 ILD 99.8125 TENS 2. 4668 DRHO 35.3516 DPHI -999.2500 TENS ,3.5675 ILO 95. 0000 TENS Z. 3711 DRMO 37°5977 DPHI -999.2500 TENS 3.3613 ILO 118,1250 TENS 2.3691 DRHO 37.7441 DPHI -999.25.00 TENS 3.7196 ILO 121.7500 TENS 2.3496 DRHO 45.8496 DPHI -999.2500 TENS 3.1142 ILO 75. 3750 TENS 2.5020 DRMO 32.4219 OPHI -999.2500 TENS 1.9728 ILD 101.9375 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 TENS 2.5407 ILO 115.9375 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 4.0716 ILM 4192'0000 GR -999.2500 -999.2500 4. 0143 tLM 4104. 0000 GR O. 0757 NRAT 16-9117 NCNL -999:.2500 0.0156 17.0301 -999.2500 ILM GR NRAT NCNL 3.3976 ILM 3894.0000 GR 0.0Z78 NRAT 18.2137 NCNL -999.2500 2.6124 ILM 4160.0000 GR 0.1440 NRAT 8.9816 NCNL -999.2500 1.9630 ILM 415Z.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 2.4283 ILM 4080.0000 GR -999.2500 NRAT -999.2500 NCNL 3.363,3 2352.0000 3.0250 118.1250 3.3867 ZZ62.O000 3.6875 1Z1.7500 3.8320 2190.0000 2.7883 75.3750 3.0000 2292.0000 1.9954 -999.2500 -999.2500 -999.2500 2.4591 -999.2500 -999.2500 -999.2500 LVP 010.M02 ~VERIPICATION LISTING PAGE 7 FCNL -999.2500 GR 9EPT 7700.0000 SELU S~P -82-2500 GR CALI RHOO RNRA NPHI FCNL -999.2500 GR DEPT SP ALI NRA FCNL -999.2500 CALI RNRA FCNL 7500.0000 SFLU -67.75.00 GR -999.2500 GR DEPT SP CALI RNRA FCNL -999.2500 GR DEPT SP CALI RNRA FCNL '7300.000:0 SFLU -44.2500 GR -999.2500 RHOB -999.2500 NPHI -999.2500 GR DEPT SP CALI RNRA FCNL 7200.0000 SFLU -63.2500 GR -999.2500 RHOB -999.2500 NPHI -999.2500 GE DEPT SP CALl RNRA FCNL 7100.0000 SFLU -71.8750 GR -999.2500 RHDB -999.2500 NPHI -999.2500 GR DEPT SP CALI RNRA FCNL ?000.0000 SFLU -65.6875 GR -999.2500 RMOB -999.2500 NPMI -999.2500 GR DEPT SP CALI RNRA 6900.0000 SFLU -76.3750 GR -999.2500 RHOB -999.2500 NPHI -999.2500 TENS: ILO TENS -999.2500 ,M -999.2500 TENS 2.9963 IL 117.5000 TE~S -999.2500 -999. 2500 TENS 3. 4940 1 I0.50,00 '-9~9.250 -999.25,00 -999. 2500 -999.2500 ILD 3.4413 ILM TENS 3864'0000 GR RHO -999.2200 NRAZ PHi -999o2500 NCN TENS -999.2500 4.5o1 , ZIP B8o9375 TENS -999.2500 DRHD NRAT -99'9.2500 DPHI NC'NL -999.2500 TENS -999.2500 2.6414 .10.3.2500 -999.2500 -99'9.2500 -999.2500 3.9239 109.9375 -999.2500 -999.2500 -999.2500 3.0176 95.0625 -999.2500 -999.2500 -999.2500 3.1725 110.8750 -999.2500 -999.2500 -999.2500 2.3854 94.9375 -999.2500 -999.2500 ILD 3.4331 ILM T E N S 38 g: 4 - ~0000 .G R' DR'HO -999.2500 NR~T DPHI -999. 2500 NCNL TENS -999.2500 ILO 4.2115 ILM TENS 3854.0000 GR DRHO -999.2500 NRAT OPHI -999.2500 NCNL TENS -999.2500 ILD 3.0359 ILM TENS 4014.0000 GR DRH:O -999.2500 NRAT DPHI -999.2500 NCNL TENS -999.2500 ILD 3.6491 ILM TENS 3664.0000 GR DRHO -999.2500 NRAT DPHI -999.2500 NCNL TENS -999.2500 ILD 2.9826 ILM TENS 3564.0000 GR DRHO -999.2500 NRAT DPHI -999.2500 NCNL 2.3920 -99:9-2500 3.0986 '999.2500 3 · 3996 - 99:9.25, :00 4.1607 .-999-2500 -999.2500 -999'2500 3.4913 '999'2500 -999.2500 -999.2500 4.2038 -999.2500 -999.2500 -999.2500 3.0437 -999.2500 -999.2500 -999.2500 3 · 6093 -999.2500 -999.2500 -999.2500 3.0292 -999.2500 -999.2500 -999.2500 LVP 010.H02 VERIFICATION LISTING PAGE 8 FCNL -999.2500 GR DEPT S'P ALi NRA F£NL DEPT sP CALl RNRA FCNL FCN'L sDEPT C A'LI RNRA FCNL DEPT SP CALI RNRA FCNL DEPT SP CAtI RNR~ FCNL OEPT SP CALi RNRA FCNL DEPT SP CALI RNRA FCNL DEPT SP CALI RNRA 6800.0000 SFLU -73°8'750 -999.2500 RHOB -999o250:0 NP:HI -999.2500 GR FLU R -999.2500 GR 6600.000,0 SFLU -53.8125 GR -_~99.2500, RHOB 6500-0000 SFLU -68.2500 GR -999.2500 RHOB -999.2500 NPHI -999.2500 GR 6400.0000 SFLU -67.3125 GR -999.25'00 RHDB -999.2500 NPHI -999.2500 GR 6300.0000 S:FLU -71.2500 GR -999.2500 RHOB -999.2500 NPHI -999.2500 GR 6200.0000 SFLU -67.3750 GR -999.2500 RHOB -999.2500 NPHI -999.2500 GR 6100.0000 SFLU -67.1875 GR -999.2500 RHOB -999.2500 NPMI -999.2500 GR 6000.0000 SFLU -74.8125 GR -999.2500 RHOB -999.2500 NPHI -999.2500 -9'99. 2500 2.5929 106.8750 -999.2500 2.8210 95° 2500 -999.2500 -999, 2500 -999. Z500 3.1913 100.8750 -999,2500 .- 999.250'0 -999.2500 3.2138 101o0,625 -999.25'00 -999.2500 -999. Z500 2.7632 101.3125 -999.2500 -999.2500 -999.2500 3.2225 101.0000 -999.2500 -999°2500 -999.Z500 3.0691 98. 0000 -999.2500 -999.2500 -999.2500 2.4729 83.8750 -999.2500 -999.2500 TENS ILO TENS' TENS ILO TENS TENS ILO TENS OR.HO DPHI TENS ILD TENS DRHO DP'HI TENS ILO TENS DRHO DPHI TENS ILO TENS DRHO DPHI TENS ILO TENS DRHO DPHi TENS ILO TENS DRHO DPHI TENS ILO TENS DRHO DPHI -999.2500 2.9541 ILM -999.2500 2.6923 ILM 3464-0000 GR -999.2500 -999. 2500 NRAT - g 9 9- 2:5 0 N C N L -999.2500 3.3438 ILM 3324.00:00 GR -999.2500 NRAT 999'2500 NCNL -999..2500 -99:9.2500 NRAT -999.2500 NCN'L -999.2500 3.0329 ILM 3350.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 3.4276 ILM 32~0.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 3.4823 ILM 3124o0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 2.8329 ILM 3054.0000 GR -999.2500 NRAT -999.2500 NCNL 2.9363 -99:-2~,0.0 i999.z5oo 999. zsoo 2.6861 -999'25:00 -9'99.2500 -999.2500 3.2855 --99'9'2500 -999.2500 -999.Z500 3.407I -999.2500 -999.2500 -999.2500 2.9419 -999.2500 -999,2500 -9'99.Z500 3.3617 -999.2500 -999.2500 -999.2500 3.3617 -999.2500 -999.2500 -999.2500 2.7415 -999.2500 -999.2500 -999.2500 LVP 010'H02 VERIFICATION LISTING PAGE 9 FCNL -999.2500 GR DEPT 5900.0000 SFLU SP -67.50:00 GR FCNL -999.2500 GR FCNL -999.2500 GR 5700.0000 SFLU -72.'1Z50 GR FCNL -999.2500 GR CALI RNRA FCNL -999.2500 GR '~PT 5500.0000 S'FLU -77.5625 GR CALI -999.2500 RHOB RNRA -999,2500 NPHt FCNL -999,2500 GE DEPT 5400.0000 SFLU SP ,-82.6875 GR CALI -999.2500 RHOB RNRA -999.2500 NPHI FCNL -999.2500 GR DEPT 5300.0000 SFLU SP -67.6875 GR CALI -999.2500 RHDB RNRA -999.2500 NPHI FCNL -999.2500 GR DEPT 5200.0000 SFLU SP -999.2500 GR CALI -999.2500 RHOB RNRA -999,2500 NPHI FCNL -999.Z500 GR DEPT 5100.0000 SFLU SP -999.2500 GR CALi -999.2500 RHOB RNRA -999.2500 NPHI -999-2500 -999.250 -999.250~ -999.2500 TENS ILD TENS -999.2500 3.4262 ILM 3.3370 2974~:000'0. :GR -999-250'0 T E NS DRMD DPHI -999.2500 TENS -999.2500 1.2537 ILM 1.3302 Z 920 * 0:000 GR -9:99.: 25'00 -999.2500 2,677i ILD 3.0311 ILM: 2.9325 86, 0,625, TENS 2.764'0000 GR -9'99'2500 -999.25,00 TENS 2.3264 ILO. g0.[875 TENS -99 2500 DRHO DPHI 2500 -999.2500 TENS 2.8687 ILD t05.0'000 TENS -999.25-00 DRHO -999.2500 DPHI -999.2500 TENS 1.5129 ILD 79.6875 TENS -999.2500 DRMO -999.2500 DPHI -999.2500 TENS 2.8729 ILO 81.6875 TENS -999.2500 DRHO -999.2500 OPHI 108.3750 TENS -999.2500 ILD -999.2500 TENS -999.2500 DEMO -999.2500 OPHI 56.1875 TENS -999.2500 ILO -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 °!0000 'GE -999,2500 NEAT 999..,25'00 NCNL -999.2500 -999.2500 N.R.AT -999.25'00 NCNL -999,2500 1,9835 ILM 2754.0000 GR -999.2500 NEAT -999,2500 NCNL -999.2~00 2.9624 ILM Z754,0000 GR -999.2500 NRAT -999.Z500 NCNL Z624,0000 -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL Z694.0000 -999.2500 ILM -999.2500 GR -999.2500 NEAT -999.2500 NCNL Z.ozg! 2500 -999.2500 -999..2500 2.6458 -999,2500 -999.250'0 -99:9,2500 1.7138 -999.2500 -999.2500 -999.2500 3.0099 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 'LVP 010.H02 VERIFICATION LISTING PAGE FCNL -999.2500 GR EPT P CALI RNRA FCNL DEPT SP ]9919.2500 RHOB 999'2500 NPHI -999.2500 GR _~900.0000 S~LU 999..2500 G FCNL -999.2500 DEPT 4800-0000 SP -999.2500 F C N L - 999 . 25~00 GR SF. LU GR RHOB NPHZ GR 4700.0000 SFLU -999.2500 GR CA~AI -999.2500 RHOB RN -999'2500 NPHI FY L -999.2500 GR EPT 4600.0000 SFLU P -999.2500 GR CALI -999.2500 RHaB RNRA -999.2500 NPHI FCNL -999.2500 GR DEPT 4500.0000 SFLU SP -999o2500 GR CALI -999.2500 RHO~ RNRA -999.2500 NPHI FCNL -999.2500 GR DEPT 4400.0000 SFLU SP -999.2500 GR CALI -999.2500 RHOB RNRA -999.2500 NPHI FCNL -999.2500 GR DEPT 4300.0000 SFLU SP -999.2500 GR CALI -999.2500 RHDB RNRA -999.2500 NPHI PCNL -999.2500 GR DEPT 4200.0000 SFLU SP -999.2500 GR CALI -999.2500 RHD~ RNRA -999.2500 NPHI 59.5000 TENS ILD TENS -999. 2500 DRHO -999-2500 DPHI 68. 62~ TENS -999-2500 ILO -999'2500 TENS -999.2500 ORHO -999.2500. DPHI 52.5000 TENS 58.9687 ILD TENS DRHO TENS -999.25;00 -999.2500 -999.2500 -999.2500 61.6250 IL TENDs DRHD DPHI TENS -999.2500 -999.2:500 -999.2500 -999.2500 46.4375 ILD TENS DRHO DPHI TENS -999.2500 -999.2500 -999.2500 -999.2500 64.0625 ILD TENS DRHO DPHI TENS -999.2500 -999.2500 -999.2500 -999.2500 65.9375 ILO TENS DR HO DPHI TENS -999.2500 -999.2500 -999.2500 -999.2500 48.031.3 ILO TENS DRHO DPHI TENS -999.2500 -999.2500 -999.2500 -999.2500 ILD TENS DRHO DPHI 2680.0000 -999.2500 ILM 2~00 Ga 2680.0000 -999.2500 !LM -999.2500 -999'2,500 GR 999.2500 -999.2500 NRAT- -999.2500 ~999.2500 NCNL '999'2500 2664.0'000 -999.2500 'ILM -999°2500 Z614.0000 -999.2500 ILM -999:'2500 GR -999.2500 NRAT -999.2500NCNL 2544.0000 -999.2500 ILM -999.2500 GR -999.2500 NRAT -999-2500 NCNL 2474.0000 -999.2500 ILM -999-2500 GR -999,2500 NRAT -999.2500 NCNL 2550.0000 -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 2504.0000 -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 2460.0000 -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL ~999..2500 ,19:9:9'2500 · -999.2500 -99'9.2500 -999.2500 -999-250'0 -999.2500 -999.2500 -999.2500. -999.250:0 -999.2500 -999.2500 -999.2500 -999.2500 -9'99.2500 -999.2500 -999.2500 -999°2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 LVP'OIO'H02 VERIFICATION LISTING PAGE FCNL -999.2500 GE 56.5313 ~PT ~100'0000 SFLU -999'2500 GR = 999.2500 RHOB -999.2500 999-2500 NPHI -999.2500 FCNL -999.2500 GR ~1o0313 CALI RHOB RNRA NPHI FCNL .-999.2500 GR 53.7813 CALl PCNL -999.2500 GR 4'0.0625 DEPT -999.2500 SP -999-2500 C~LI -999.2500 RHO8 -999.2500 RNRA -999.250'0' 'NPHI -999.2500 FCNL -999.1500 GR 39.4688 DEPT 3700.0000 SF.LU -999.2500 SP -999-2500 GR -999.2500 CALI -999.2500 RHO8 -999.2500 RNRA -999.2500 NPHI -999.2.500 FCNL -999.2500 GR 60.2500 DEPT 3600.0000 SFLU -999.2500 SP -999.2500 GR -999.2500 CALI -999.2500 RHO~ -999.2500 RNRA -999.2500 NPHI -999.2500 FCNL -999.2500 GR 51.6875 DEPT 3500.0000 SFLU -999.2500 SP -999.2500 GR -999.1500 CALI -999.2500 RHOB -999.2500 RNRA -999.Z500 NPHI -999.2500 FCNL -999.2500 GE 67.8125 DEPT 3400.0000 SFLU -9~9.2500 SP -999.2500 GR -999.2500 CALI -999.2500 RHOB -999.2500 RNRA -999.2500 NPHI -999.2500 FCNL -999.2500 GR 37.5625 DEPT 3300.0000 SFLU -999.2500 SP -999.2500 GR -999.2500 CALl -999.2500 RHOB -999.2500 RNRA -999.2500 NPHI -999.2500 TENS 2,454. 0000 DRHO -999.2500 NRAT DPHI -999'2500'! :NCN:L TENS 2440.0000 -999.2500 iLM 9.99'2:5:00 TENS ENS 2380.0000 TENS 2364.0000 ILD TENS DRHO DPHI TENS ILO TENS DRMO DPHI TENS ILO TENS DRHO DPHI TENS ILO TENS DRHO OPHI TENS ILD TENS DRHO DPHI TENS ILO TENS DRHO OPHI -99'9.2500 ILM -999'*:2500 GR 2324.0000 -999.2500 ILM -999.2500 GE -999.2500 NRAT -999.2500 NCNL 2290.0000 -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL Z304.0000 -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 2254.0000 -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL Z184.0000 -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL .-999.2500 '999.2500 -999.2500 -999-2:50:0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 LVP OlO'M02 VERIFICATION LISTING PAGE 12 FCN'L -999.2500 GR 3200.0000 SFLU -999. 2500 GR CALI -999.2500 RHOB RNRA ggg.zs. 00 NPHt F.CNL -999.Z500 GR EPT P CALI R'NRA FCNL 3100.0000 SFLU '999.2500 GR -999.2500 GR DE PT SP CALI RNRA FCNL 3000.0000 SFLU -999.2500 GE -999.2500 GR C,A, LI RNRA FCN'L 2900.00,00 SFLU -999.2500 GR -999.2500 RM08 -999,2500 NPHI -999.2500 GR ~PT CALI RNRA FCNL DEPT SP CALI RNRA FCNL 2700.0000 SFLU -999.2500 GR -999.2500 RHOB -999.2500 NPHi -999.2500 GR DEPT SP CALI RNRA FCNL 2600.0000 SFLU -999.1500 GR -999.2500 RHDB -999.2500 NPHI -999.1500 G'R DEPT SP CALI RNRA FCNL 2500.0000 SFLU -999.2500 GR -999.2500 RHOB -9gg.zsO0 NPHI -999.2500 GR DEPT SP CALI RNRA 2400.0000 SFLU -999.2500 GR -999.2500 RHOB -999.2500 NPHI 37.3750 TENS Z164.0000 -999.2500 ILD -999,2500 ILM -999.2500 '-999.2500 TENS' -999' 2500 'GR -999'2500 -999.2500 OR'MC -~ -999. 2500 OPM[ 60.6250 TENS 2124.0000 --( DRHO -999.2500 NRAT OPHI -999- 2500 NCNL 46, 9375 TENS 2164, 0000 999.2500 egg- Z500 -999.2500 -999.2500 -999.2500 -999-2500 32.2813 ILO TENS -999.2500 I~M -999.2500:G TENS 2050.0000 -999.2500 -999,2'500 -999.2500 -999.2500 30.1250 ILO TENS DRHO DPHI TENS 1999.2~00 -999.2500 NRAT · - 999.2500 N:CNL 1990,0000 --( -999.2500 -999. 2500 -999.2500 -999 . 25 O0 ~+Z. 3750 ILO TENS DRMO DPMI TENS -999.2500 NRAT -999.2500 NCNL 1990.0000 -999.2500 --999-2'500 -999.250'0 -999'2500 -999.2500 -999.2500 -999.2500 -999.2500 29.6875 ILD TENS DRMO DPHI TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 1995.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.1500 -999.2500 -999.2500 -999.2500 46.7188 ILO TENS DRHO DPMZ TENS' -999.Z500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 1915.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 51.6250 ILD TENS ORHO DPHI TENS -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 1875.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ILO TENS ORHO DPHI -999.2500 ILM -999.2500 GA -999.2500 NRAT -999.2500 NCNL -999.2500 -999.2500 -999.2500 -999.2500 LVP' 010oHO2'VERIFICATIDN LISTING PAGE FCNL -999.2500 GR 47.4688 TENS 0w . ~mPT 2300 0000 SF:L.U aP -99:9.2500 GR -999.2~00 RHDB -999.2500 DRHD -999-250i0 NPHI '999'2500 DPHI FCNL -999.2500 GR 33.2500 TENS DEPT 2200.0000 SFLU SP '999- 2500 GR ]999.2500 RHD~ g99'-2500~ NPHI FCNL -999.2500 GR 33.1562 TENS CALI RNRA F CNL 100.0000 SFLU 1999'2500 GR -999.2500 GR -~99.2500 ILO - 99.2500 TENS -999.2500 DRHO -999o2500 DPHI 27.5156 TENS DEPT ZO00.O000 SFLU SP -99'9.2500 GR CALI -999.2500 RHOB RNRA -999.2500 NPHI FCNL -999.1500 GR -999. 2500 ILD -999.25.00 TENS -999.2500 DRHO -999. 2500 DP'HI 37.2187 TENS DEPT 1900..0000 SFLU SP -999.2500 GR CALl -999.2500 RHOB RNRA -999-2500 NPHI FCNL -999.2500 GR -999.2500 ILD -999.2500 TENS -999.2500 DRHO -999.2500 DPHI ~5.4375 TENS DEPT 1800.0000 SFLU SP -999.2500 GR CALI -999.2500 RHGB RNRA -999.2500 NPHI FCNL -999.2500 GR -999.2500 ILO -999.2500 TENS -999.2500 DRHO -999.2500 DPHI 48.0938 TENS DEPT 1700.0000 SFLU SP -999.2500 GR CALi -999.2500 RHOB RNRA -999.2500 NPHI FCNL -999.2500 GR -999.2500 ILO -999.2500 TENS -999.2500 DRHO -999.2500 DPHI 26.4375 TENS DEPT 1600.0000 SFLU SP -999.2500 GR CALl -999.2500 RHOB RNRA -999.2500 NPHI FCNL -999.2500 GR -999.2500 ILO -999.2500 TENS -999..2500 DRHO -999.2500 OPHI 34.5000 TENS DEPT 1500.0000 SFLU SP -999.2500 GR CALl -999.2500 RHOB RNRA -999.2500 NPHI -999.2500 ILD -999.2500 TENS -999.2500 DRHO -999.2500 DPHI 1890.0000 -999.2500 ILM 999~2500GR -999.2500 -999.2500 1885.0000 -999.2500 ILM 99,9':25!00 G:R ]999.2500 999-2 500 1760.0000 ] 999.2500 ILM. -~99.Z500 9'9'9-2500 : GR :- 99.25:0,0 -999.2500 999'2500 1780. 0000 -999..2500 ILM -999-.2500 GR -999.2500 NRAT 999.2500 N'CNL 1765. 0000 -999.2500 -999.2500 tLM GR NRAT NCNL 1790.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ILM -9'99.2500 GR -999.2500 NRAT -999.250.0 NCNL 1705.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ILM -999.2500 GR -999.2500 NRAT -999.2500 NCNL 1650.0000 -999.2500 -999.2500 -999.2~00 -999.2500 -999.2500 ILM -999.2500 GR -999.2500 NR~T -999.2500 NCNL 1660.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ILM -999.2~00 GR -999.2500 NRAT -999.2500 NCNL -999.2500 -999.2500 -999.2500 -999.2500 LVP 010.H02 VERIFICATION LISTING PAGE FCNL -999.2500 GR Z7.7969 TENS 1665.0000 EPT' P FCNL -999.2500 HDm '999.2500 NPMI -999.2500 GR ILD -999.2500 ILM -999.2500 TENS -999'2500 GR -999.2500 -999,2500 DRHO -99.9,2500 NRAT -999,2'500 -999,2500 DPMI -999'2500NCNL -99'9.2500 24.4844 TENS 1575.0000 DEPT SP A'LI NRA FCNL 1300,0000 SPLU -999'2500 GR -999.2500 GR -999,2500 ILO -999.2500 ILM -999' 2500 TENS '999'2500 GR -999.2500 NRAT -999-250.0 'NCNL 36.7500 TENS 1615.0000 CALI RNR A FCNL SFLU GR -999.2500 GR -999.2500 ILD -~ M -999.2500 TENS - DRHO -999,~500 NRAT DPHI -99'9-2500 NCNL 43.5000 TENS 15ZS.0000 DEPT 1100.0000 SFLU SP -999.2500 GR ALI -999.2500 RHOB NRA -999.2500 NPHI FCNL -999.2500 GR -9'99.2500 ILO -999.2500 'TENS 57.5938 TENS' -999,2500 ILM -999-2500 GR 1455.0000 -999.2500 -99,9,,2500 -999.2500 -999.2500 DEPT 1000o00'00 SFLU SP -999.2500 GR CALI -999.2500 RHOB RNRA -999..2500 NPHi FCNL -999.2500 GR -999.2500 ILD -999,, 2500 TENS -999.2500 DRHO -999,2500 DPHI 54,3750 TENS -999.2500 ILM -999-2500 GR -999.2500 NRAT -999,2500 NCNL t400.0000 -999.2500 -999.Z500 -999.2500 -999.25.00 DEPT 979.5000 SFLU SP -999.2500 GR CALl -999.2500 RHOB RNRA -999.2500 NPHI FCNL -999.2500 GR -999.2500 ILD -999,2500 TENS' -999.2500 DRHO -999,2500 DPHI 53.8437 TENS -999.2500 ILM -999-2500 GR -999.2500 NRAT -999.2500 NCNL 1385.0000 -999.2500 -999.2500 -999.2500 -999.2500 ~ FILE TRAILER *~ FILE NAME :EDIT .001 SERVICE NAME : VERSIDN ~ : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : NEXT FILE NAME : EOF ****~'**~'*~' ** TAPE TRAILER *~ SERVICE NAME :EDIT DATE :87/02/17 LVP 010.H02 VERIFICATIDN LISTING PAGE I5 ORIGIN :7219 TAPE NAME : CON'TINUATION # :0! 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