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Home My WebLink About186-189MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3Q-12 KUPARUK RIV UNIT 3Q-12 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 3Q-12 50-029-21677-00-00 186-189-0 W SPT 6361 1861890 3000 1730 1733 1732 1731 50 50 50 50 REQVAR P Josh Hunt 8/28/2024 This is a 2 year MIT-IA required by AIO 2C.002. This well was tested to a starrting pressure of 3300 psi. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3Q-12 Inspection Date: Tubing OA Packer Depth 190 3290 3130 3110IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240828162243 BBL Pumped:4.6 BBL Returned:4.4 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 999 9 9 99 9 9 9 AIO 2C.002 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 14:19:23 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 30, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3Q-12 KUPARUK RIV UNIT 3Q-12 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 3Q-12 50-029-21677-00-00 186-189-0 W SPT 6361 1861890 3000 1777 1780 1778 1778 230 290 290 290 REQVAR P Bob Noble 8/13/2022 MITIA as per AIO 2C.002 to max pressure. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3Q-12 Inspection Date: Tubing OA Packer Depth 700 3300 3150 3120IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN220814154318 BBL Pumped:3.8 BBL Returned:3.4 Tuesday, August 30, 2022 Page 1 of 1 9 9 9 9 99 9 9 9 AIO 2C.002 James B. Regg Digitally signed by James B. Regg Date: 2022.08.30 15:36:05 -08'00' Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Friday, October 18, 2019 12:03 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU injector 3Q-12 (PTD 186-189, AIO 2C.002) OA Monitor End Attachments: KRU 3Q-12 TIO plot 90 -day 10-18-19.pdf Chris, KRU injector 3Q-12 (PTD 186-189, AIO 2C.002) has completed its extended monitor period to confirm that integrity between the IA and OA exists. The IA and OA pressures were adjusted during the monitor to look for communication between the annuli. Based on the monitor, the OA appears to not communicate with the IA. CPA[ plans to allow the well to continue water only injection under the conditions of the existing AIO 2C.002. Attached is a 90 -day TO plot. Please let us 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 Waiiace, Chris D (CED) From: Well Integrity Compliance Specialist WNS &CPF3 <n2549@conocophillips.com> Sent: Wednesday, September 18, 2019 9:08 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: KRU 3Q-12 (PTD 186-189, AIO 2C.002) Suspect OA Behavior Attachments: 3Q-12 AnnComm Surveillance TIO 9.18.19.pdf, 3Q-12.pdf Good Morning Chris, KRU injector 3Q-12 (PTD 186-189, AID 2C.002) underwent diagnostic testing to investigate the suspect slow OA pressure increase. The OA pressure was brought above the IA pressure to verify that the OA is not being charged by the formation. During this time, no pressure communication was evident. Operations charged the IA when the well was swapped from produced water to seawater injection on September 4t1. For the remainder of the monitor the IA pressure was above the OA pressure and the well continued to not exhibit IA x OA communication. The 30 -day monitor concludes tomorrow, and we would like to extend the monitor period another 30 days to confirm that the well continues exhibiting integrity between the IA an OA. Please let me know if you have any questions or disagree with this plan. Attached is a 90 -day TIO chart and schematic. Sincerely, Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhi►lips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisleCo)cop.com From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Tuesday, August 13, 2019 2:44 PM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: RE: KRU 3Q-12 (PTD 186-189, AID 2C.002) Suspect OA Behavior Hello Chris, KRU injector 3Q-12 (PTD 186-189, AID 2C.002) underwent diagnostic testing to investigate the suspect slow OA pressure increase. On 8/12/19 the well passed positive and negative inner casing pack -off tests, an MIT -OA to 1800 psi, and an MIT -IA to 3000 psi. The well is currently shut in due to plant maintenance. When plant maintenance is complete CPAI intends to conduct a 30 -day monitor of the OA with the plan to keep the OA pressure above the IA to verify that the OA pressure is not being charged by the formation. We will follow up with a path forward depending on the results of the monitor. We will likely consider cancelling the existing waiver and applying for a new AA that encompasses both the TxIA on gas injection and potential IA x OA communication on water injection. Please let me know if you have any questions or disagree with the plan forward. Attached are the MIT results. Sinc rely, ScwwCarlisI&(H"kt v)/1Zaaw1Ka.at7k Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549C&cop.com Cell: 907-331-7514 1 sara.e.carlisle(@cop.com From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Sunday, August 4, 2019 4:36 PM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU 3Q-12 (PTD 186-189, AIO 2C.002) Suspect OA Behavior Chris, KRU injector 3Q-12 (PTD 186-189, AIO 2C.002) is exhibiting suspect slow OA pressure increase. The OA trend was noted today during a TIO plot review. The well has an existing Administrative Approval for water -only injection due to known TxIA during gas injection. CPAI intends to shut-in and freeze protect the well as soon as operationally possible. CPAI will plan to perform diagnostics and follow-up with a path forward depending on the results. Attached is a 90 -day TIO plot. 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: Tuesday, August 13, 2019 2:44 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: KRU 3Q-12 (PTD 186-1$�AIO 2C.002) Suspect OA Behavior Attachments: 3Q-12 MIT Form.xlsx Hello Chris, KRU injector 3Q-12 (PTD 186-189, AIO 2C.002) underwent diagnostic testing to investigate the suspect slow OA pressure increase. On 8/12/19 the well passed positive and negative inner casing pack -off tests, an MIT -OA to 1800 psi, and an MIT -IA to 3000 psi. The well is currently shut in due to plant maintenance. When plant maintenance is complete CPAI intends to conduct a 30 -day monitor of the OA with the plan to keep the OA pressure above the IA to verify that the OA pressure is not being charged by the formation. We will follow up with a path forward depending on the results of the monitor. We will likely consider cancelling the existing waiver and applying for a new AA that encompasses both the TxIA on gas injection and potential IA x OA communication on water injection. Please let me know if you have any questions or disagree with the plan forward. Attached are the MIT results. Sincerely, SarwCa-U*lp-,,(if" v)/2aJveVKautk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle0cop.com From: Well Integrity Compliance Specialist WNS & CPF3 3t : Sunday, August 4, 2019 4:36 PM To: chri . Ilace@alaska.gov Cc: CPA Wells <n1030@conocophillips.com> Subject: KRU 3Q-12 186-189, NO 2C.002) Suspect OA Behavior Chris, KRU injector 3Q-12 (PTD 186-189, AIO 2C.002) is 'biting suspect slow OA pressure increase. The OA trend was noted today during a TIO plot review. The well has an existing inistrative Approval for water -only injection due to known TxIA during gas injection. CPAI intends to shut-in and freeze pro the well as soon as operationally possible. CPAI will plan to perform diagnostics and follow-up with a path forward depen os plan the results. Attached is a 90 -day TIO plot. Please let us know if you have any questions or disagree with thin. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Sunday, August 4, 2019 4:36 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 3Q-12 (PTD 186-189, AIO 2C.002) Suspect OA Behavior Attachments: KRU 3Q-12 TIO Plot 90 -day 8-4-19.JPG Chris, KRU injector 3Q-12 (PTD 186-189, AIC) 2C.002) is exhibiting suspect slow OA pressure increase. The OA trend was noted today during a TIO plot review. The well has an existing Administrative Approval for water -only injection due to known TxIA during gas injection. CPAI intends to shut-in and freeze protect the well as soon as operationally possible. CPAI will plan to perform diagnostics and follow-up with a path forward depending on the results. Attached is a 90 -day TIO plot. 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 State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,September 16,2016 TO: Jim Regg P.I.Supervisor �ezq c fr. 1 i� SUBJECT: Mechanical Integrity Tests (� CONOCOPHILLIPS ALASKA INC 3Q-12 FROM: Brian Bixby KUPARUK RIV UNIT 3Q-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-12 API Well Number 50-029-21677-00-00 Inspector Name: Brian Bixby Permit Number: 186-189-0 Inspection Date: 9/15/2016 Insp Num: mitBDB160915163705 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 3Q-12 W V 6361 'r 1920 1920 - 1920 1920 • Well Type Inj TVD - Tubing� PTD 1861890 , Type Test SPT Test psi, 3000 - IA 350 3310 , 1 3190 - 1 3150 - Interval REQVAR P/F P ,/ OA 125 150 , 150 , 150 Notes: AIO Number is 2C.002 ,/ %ANNE) J iUi N 2 I) 2.01'? Friday,September 16,2016 Page 1 of 1 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. Organization (done) RESCAN Color items: Grayscale items: Poor Quality Originals: Other: ~r4~ ~~ ORGANIZED BY: DIGITAL DATA Diskettes, No. D Other, No/Type NOTES: BEVERLY BEEN VINCENT SHERYL~AR~-"~ LOWELL ProjeCt Proofing OVERSIZED (Scannable) D Maps: o Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds D Other By: Date: PROOFED BY: BEVERLY BEEN VINCENT SHERYL MARIA LOWELL DATE: Isl Scanned (do.e) I[ll[llllllllllllll PAGES:~ ~ (at the time of scanning) SCANNED BY' BEVERLY BEEN VINCE~ARIA LOWELL RESCANNED BY: BEVERLY BEEN VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file://43/~-.'//O II PAGES: DATE: /SI Quality Checked (done) RevlNOTScanned.wpd ~~ Conoc P ' ' o hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder Alaska Qil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~ ~~~,n ~ ~ ~Tr~~~ t.- ~ ~ bi~ bwhY~ ..~:.a ~ ~ . Jf.?~+:i Dear Mr. Maunder: ~ ~'~z1-I ~~ ~~ ` ~ 3~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~' 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9th and 10~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~G~" ( MJ Lov land ConocoPhillips Well Integrity Projects Supervisor • ~ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 08/11/09 ~.. ~~ ~~, e .,,, ., ell Name PI # TD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date ~ u v~c Corrosion inhibitor ~ c~a~ Corrosion inhibitor/ sealant date bbls a~ 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" n/a 17" Na 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-106 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" , n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9l2009 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 Na 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 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7l30l2009 4.25 8/8/2009 3Q-07 3Q-12 50029216820000 50029216770000 1861940 1861890 6" 7" n/a n/a 6" 7" n/a Na 1.7 2.97 8/9/2009 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30l2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'5" 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 Toy Jim Regg P.I. Supervisor ~ ~~ (G'~~ ~ ~~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October OI , 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-12 KUPARUK RIV [JNIT 3Q-12 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv .~ Comm Well Name: KUPARUK RIV UNIT 3Q-12 API Well Number: 50-029-21677-00-00 Inspector Name: Bob Noble Insp Num: mitRCN080927182134 permit Number: 186-189-0 ~ Inspection Date: 9/2s/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Q-lz Type Inj. i G ! TVD 6361 IA ~ Is00 2250 2240 i 2240 P T 1a61s9o jTypeTest ~ SPT ~ Test psi 22so ~ pA 600 600 600 ! 600 Interval 4YRTST p~F P ~ Tubing i 36s0 3650 3650 3650 Notes: k {{tt ~ _ Wednesday, October O 1, 2008 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Y~ ~/Z4 tOt' P.I. Supervisor)'~ rr DATE: Wednesday, August 11,2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-12 KUPARUK RIV UNIT 3Q-12 FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv 5l31-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3Q-12 API Well Number: 50-029-21677-00-00 Inspector Name: John Crisp Insp Num: mitJCrO40810173535 Permit Number: 186-189-0 Inspection Date: 8/8/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Q-12 Type Inj. s TVD 6798 IA 1350 3025 2750 2550 P.T. 1861890 TypeTest SPT Test psi 1590.25 OA 0 0 0 0 Interval 4YRTST PIF I Tubing 2100 2100 2100 2100 Notes: The IA took 11 bbl's fluid to achieve test pressure. I requested CIP Operator to allow pressure to stabilize & retest. Wednesday, August 11,2004 Page 1 of! MEMORANDUM TO: Julie Huesser, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission / z~";~g' 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: I 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, 4 wells, 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: Kupan~ / KRU / 3Q Pad Separator psi: LPS HPS 12/1/00 Well· Permit Separ Set L/P ·Test Test Test Date Oil, WAC, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 3Q-01 1911250 . 3Q-02 1870040 3700 2000 1750 P P WAG 3.Q-03 1911260 3,Q-04 1911240 · 3Q-06 1861950 3,~-07 1861940' 3Q-08A 1971930 3Q-09 1861860 ~ ~Q-10 1861870 3Q-ll 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: Remarks: Misc tests on Wag wells ~9/a/aa Paee 1 of 1 SVS KRU 30 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 _ Perforate _ Pull tubing _ Alter casing _ Repair well X Other _ 2. Name of Operator Phillips Alaska Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2277' FNL, 2062' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 602' FNL, 1937' FVVL, Sec. 17, T13N, R9E, UM At effective depth At total depth 436' FNL, 1761' FWL, Sec. 17, T13N, R9E, UM 5. Type of Well: Development X Exploratory__ Stratigraphic__ Service__ 6. Datum elevation (DF or KB feet) RKB 60 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3Q-12 9. Permit number / approval number 1861890 10. APl number 50-029-21677 11. Field / Pool Kuparuk River Oil Pool 12. Present well condition summar Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 115 16" Surface 3838 9 5/8" Production 7382 7 7503 feet Plugs (measured) 6798 feet 7229 feet Junk (measured) 7253 feet Cemented 1875# Poleset 9oosx AS III & 275sx Class G 300sx Class G & 175sx AS I PBTD tagged @ 7294 Fill tagged @ 7229 (09/10/00) Measured Depth 115 3838 7382 True verticalDepth 115 3780 6684 RECEIVED Perforation depth: measured true vertical Tubing (size, grade, & measured depth) Packers and SSSV (type & measured depth) 7077', 7081', 7085', 7110' -7140' 6443', 6446', 6450', 6470' - 6496' 2 3/8", 6.5# / L-80. 7009' MD Camco 'HRP-1-SP'. 6978' MD NOV 2 0 Z000 Alaska Oil & Gas Cons. Commission Anchorage ORIGiNAl.. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation (injection) Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mci Water-Bbl 824 824 Casing Pressure Tubing Pressure 2000 3650 2000 3650 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __ Gas __ Suspended __ Service WAG Signed: /'/~-//~LJerry Dethlefs(-'""/~ Title: Phillips Wells Supervisor Date 11/15/00 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE SUNDRY NOTICE 10-404 Phillips Kuparuk Well 3Q-12 Annular Cement "Top-Job" November 3, 2000 Phillips Alaska, Inc., Kuparuk well 3Q-12 production casing has "grown" several inches to the point where the production casing hanger was no longer contacting the conductor pipe. This gas injector was subject to vibrations and required stabilizing. The cement top in the 9-5/8" x 16" annulus (OOA) was measured at 58-feet below grade. Arctic Set I cement (15.7 ppg) was pumped into the annular void (8.5 bbls) via a hose, filling from the bottom-up. The cement top was brought to the surface of the conductor casing. The State Inspector was notified of the cement job and waived attendance, but inspected the wellhead post cementing. The field Well Service Report is attached. PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(3Q-12(W4-6)). WELL JOB SCOPE JOB NUM'BER " 3Q-12 ANN-COM M 1014001842.1 DATE DAILY WORK UNIT NUMBER 11/03/00 CEMENT TOP UP ON THE OOA (9 5/8"X16") DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES DS-ANDERSON, C. NEZATICKY .... FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE K85238 230DS36QL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 0 PSI 0 PSI DALLY SUMMARY IFILLED ABOUT 60 FT OF ANNULAR SPACE BETWEEN THE SURFACE AND CONDUCTOR ( 9 5/8" X 16" ) WITH 8.5 BBL OF 15.7 PPG ARCTIC SET 1 CEMENT. CEMENT TO SURFACE. TIME LOG ENTRY 09:00 EQUIPMENT ON LOCATION. MIRU - MEASURED DEPTH OF ANNULAR VOID IS 58 FT. INSERT 60 FT OF 1" HOSE DOWN THE OOA. 09:30 FRESH WATER FROM VAC TRUCK CONTAMINATED. DUMPED THE MIX WATER. SENT APC TO GET A NEW LOAD OF MIX WATER. 11:30 VAC TRUCK WITH FRESH WATER ON LOCATION. 12:30 START MIXING CEMENT. 13:00 START PUMPING 15.7 PPG ARCTIC SET 1 CEMENT. 13:20 PUMPED A TOTAL OF 8.5 BBL OF CEMENT TO GET CEMENT TO SURFACE. 13:30 RIG DOWN RECEIVED Alaska Oil & Gas Cons. Cnrnmis_~ion Anchorage SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC DOWELL TOTAL FIELD ESTIMATE I I MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALA,% .... OIL AND GAS CONSERVATION CON',.. _;SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other J~ 2. Name of Operator ARCO Alaska, Inc 3. Address PO Bnx ]0036¢l= Anchnrag~= 4. Location of well at surface 2277' FNL, 2062' FEL, Sec At top of productive interval 519' FNL, 1862' FWL, Sec At effective depth 621' FNL, 1924' FWL, Sec At total depth 439' FNL, 1732' FWL, Sec AK .17, T13N, R9E, UM .]7, T13N, R9E, UM · 17, T13N, R9E, UM · 17, T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 60' 6. Unit or Property name Ku.oa_ru_b Piver Unit 7. Well number 3Q-12 8. Approval number #7-807 9. APl number 5O-- 029-21677 10. Pool Kuparuk River Oil Pool 11. Present well condition summary.7 Total depth: measured .503' ND true vertical 6791' TVD feet feet Plugs (measured~One Effective depth: measured 7294' MD true vertical6617' TVD Casing Length Size Structural Conductor 80 ' ] 6" Surface 4801' 9-5/8" X X X ~rxt)~Ar~ ~¢:i)~t e Production 7348' 7" xx xxL'~e~xx xx Perforation depth: feet feet Junk (measured) None Cemented Measured depth 6onductor Report Not Received 115' MD 900 SX ASII! 3838' MD & 275 SX Class G 300 SX Class G 7382' MD measured 7077'-7085' MD, 7081' MD, 7110'-7140' MD True Vertical depth 115' TVD 3776' TVD 6690' TVD true vertical6443' TVD, 6450' TVD, 6446' TVD, 6470'-6496' TVD Tubing (size, grade and measured depth) 2.875", L-80, with Tail @ 7009' MD Packers and SSSV (ty_p_e and measured depth) HRP-1 SP Pkr ~ 6978' & FVL SSSV @ 1792' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1200 BOPD 750 MCFPD - BWPD 200 psig 140 psig Subsequent to operation 2000 BWPD 1000 psig 12flfl p,!fi 14. Attachments Converted from oil producer to water injector on 12/9/87 Daily Report of Well Operations ~ Copies of Logs and Surveys Run IL} 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ,,:/_~..,~/ /(~ ~ / ~ -~'¢~,/ Title Sr. Operations Engineer Date2/25/88 Submit in Duplicate Signed /~¢,~/~,~ ,~ ,g~.~.~f~z,,Ic,~x~-2 Form 10-4~4 i~ev. 1¢-8,~ Feet ARCO Alaska, In~... ~ Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL :)NTRACTt~) REMARKS "IOPERATION AT REPORT TIME IDAYS DATE ,lOc) O- /Do,S- - /~jo 6 7/~$' l-~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ]Temp. J Chill Factor Visibility Wind Vel. Report 'F °F miles ARCO Alaska, Inc~ Post Offic. i= x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 13, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Commi s s i on Dear Mr. Chatterton: Attached in triplicate are multiple on Kuparuk wells. The wells were listed below. Applications for Sundry Approvals both conversions and fractures as Well Action Anticipated Start Date 2A-3 Conversion 2A-6 Conversion 2A-7 Conversion October 19, 1987 October 19, 1987 October 19, 1987 3K-15 Conversion October 15, 1987 3N-4 Conversion 3N-5 Conversion 3N-11 Conversion October 15, 1987 October 15, 1987 October 15, 1987 3Q-5 Conversion 3Q-12 Conversion 3Q-15. Conversion October 15, 1987 October 15, 1987 October 15, 1987 If you have Sincerely, any questions, please call me at 265-6840. G. B lwood Senior Operations Engineer GBS:pg:0117 Attachments cc' File KOE1.4-9 RECEIVED OCT 1 6 1 87 Alaska Oil & Gas Cons. Commission Anchorage .. ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichfleldCompany STATE OF ALASKA ALA~..,A OIL AND GAS CONSERVATION COk..,,~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension E) Change approved program [] Plugging [] Stimulate [] Pull tubing E~ Amend order LJ Perforate [] Other,~ 2. Name of Operator ARCO Alaska; Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 2277' FNL, 2062' FEL, Sec. 17, T13N, R9E, UN At top of productive interval 519' FNL, 1862' FWL, Sec. 17, T13N, R9E, UN At ~l,deF~, 1732' F~L, Sec. 17, T13N, R9E, UN 5. Datum elevation (DF or KB) RKB 60 6. Unit or Property name Kuparuk River Unit feet 7. Well number 3Q-12 8. Permit number 86-189 9. APl n(~:>_e;~1677 50-- 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 7503' 6791' feet Plugs (measured) feet None 7294' feet Junk (measured) None 6617' feet Casing Length Structural Conductor 80' Surface 4801' Intermediate Production 7348' Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Size Cemented Measured depth 16"Conductor Report not rec'd 115' 9-5/8" 900 Sx A.S. III 3838' 275 Sx Class "G" 7" 300 Sx Class "G" 7382' 7077' -7085', 7081', 7110' -7140' MD 6443' 6450' 6446' 6470'-6496' TVD 2.875", L-80, tbg w/tail ~ue Vertical depth 115' 3776' 669O' Packers and SSSV (type and measured depth) HRP-1 SP Pkr @ 6978' & FVL SSSV @ 1792'. 12.Attachments Description summary of proposal [] Detailed operations program E3 BOP sketch Convert to water injection. 13. Estimated date for commencing operation October 15, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby _certify that the foregoing is true and correct to tl3q best of my knowledge S i g n e d .~¢'~.~j~,l~f~, -~ .J ¢1A,, ,-~/~9 Tit la ..~ '/ Commission Use ~nly ~7 Date / ,,) ~) C 'Y/ ¢')' Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Commissioner Approval No. the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate /%17: ' ~ i .... STATEOF ALASKA ALAS~IL AND GAS CONSERVATION SSION COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDQN;ED [] SERVICE [] 2. Nan~e'~f dpera{o~ ' ' ' 7. Permit Number ARCO Alaska~ Inc. 86-189 3. Ad~lress 8. APl Number P, 0. Box 100360~ Anchorage~ AK 99510 50- 029-21677 4. Location of well at surface 9. Udkf'or Lease Name ~) ~,~ 2277' FNL~ 2062' FEL, Sec.17~ T13N~ RDE~ UN .!~,..~ . Kuparuk River Unit' ' At Top Producing Interval ~ ' icl W~ll Number . 602' FNL, 1937' FWL, $ec.17, TI3N, RDE, UN 30-12 ; . :,~. At Total Depth 11. Field and Pool 436' FNL, 1761' FWL, Sec.17, T13N, RDE, UM : Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 60' ADL 25512 ALK 2553 12. Date SPudded 13. Date T.D. Reached 14. Bate'Comp., Susp. or Aband. I15. Water Dept~, if ~)ffshore Ils. No. of Completions 12/10/86 12/14/86 05/17/87' IN/A feetMSL I 1 17?Total Depth (MD+TVD) iS.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7503'MD, 6798'TVD 7294'MD, 6623'TVD YES {~ NO [] I 1792' feet MD 1600' (approx.) 22. Type Electric or Other LogS'Run D IL/SFL/SP/Cal/GR/FDC/CNL, CBL, Gyro 23. . ..... CASING., L. tN.ER.AND CE.MEN.T. ING. R. ECORD . . . SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-~,0 Surf 115' '2 ~,,, I m 1'875# Pol eset 9-5/8" 36.0# 'J-55 · Surf 3838' i2-1/M' 900 sx AS I11 & 275 sx Class G 7" 26.0# J-55 Surf 7382' 8-1/2" 300 sx Class G & 175 st AS I 24. Perforations open to Production (MD+TvD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7077 'MD 6~,/+ 3 ' TVD 2- 7/8" 7009 ' 6978 ' 7085 'MD 6/+50 'TVD 7081 'MD 6~,~6'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7110'-71~,0'ND~n~ 6~,70'-6~,96'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Adde~dum~ dated 5/19/87~ Perforated w/1 spf~ 0e phasing' for fracture Cata ~Perforated w/12 spf~ 120e phasing . . 27. N/A .......... PRODUCTION TEST Date First Production. · Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested TEsTPRODUCTpERIoDON FORi~ OI L~BI~L GAS-MCF' '. m'! V~ A"~ ~'~:~ ' ~ B L .... ~HOKE SIZE ' GAS-O~L RATIO Fiow T'ubi'ng Casing I~re~sure CALcuLATED,a~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE. ? 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED JUN 1 ~ Alaska Oil & Gas Cons. Commission Anchorage · NOTE: Drilled RR 12/16/86.m Perforated well & ran tUlbtn.q 1./1~9/87; . . ' "~ . I Form 10-407 Rev. 7-1-80 WC3/5 :DAN I CONTINUED ON REVERSE SIDE Submit in duplicate : ', i ~ 29. '~, ~ 30. '\ i GEOLOGIC MARKERS" 'FORMATION TESTS · . NAME 6. Include interval tested, pressure data, all fluids recovered and gravity, MEAS. D'EPTH TRUE VERT. DEPTH GaR, and time of each phase. · . . ! . .Top Kuparuk C 7065' 6433' N/A Base Kuparuk: C : 7078 ' 6444' Top Kuparuk A 7078' 6444' Base Kuparuk A 7114' 6474' 31. LIST OF ATTACHMENTS Addendum (dated 5/19/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~ (i.'~t~1t}(_., .~-'~f~.Z/.k~)~._/ Title Associate Engineer Date / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 .. ADDENDUM WELL: 12/22/86 1/06/87 1/09/87 5/17/87 3Q-12 Arctic Pak well w/175 sx AS I & 60 bbls Arctic Pak. Rn CBL & gyro. Re-rn CBL to 7289' WLM TD. Rn GR/JB f/PBTD to surf. Frac Kuparuk "A" sand perfs 7077', 7081', 7085', 7110'-7140' in 11 stages per procedure dated 5/7/87 as follows: Stage 1: 40 bbls 140° diesel 10% Musol @ 5 BPM, 3000 - 2510 psi Stage 2: "A" - 101 bbls gel diesel @ 20 BPM, 6700 - 3410 psi Stage 3: "B" - 600 bbls gel diesel @ 20 BPM, 2550 - 3650 psi Stage 4: 21 bbls gel diesel 2# 20/40 @ 20 BPM, 3650 - 3810 psi Stage 5: 40 bbls gel diesel 4# 20/40 @ 20 BPM, 3810 - 3290 psi Stage 6: 40 bbls gel diesel 6# 20/40 @ 20 BPM, 3290 - 4770 psi Stage 7: 40 bbls gel diesel 7# 20/40 @ 20 BPM, 4770 - 3540 psi Stage 8: 20 bbls gel diesel 8# 20/40 @ 20 BPM, 3540 - 3390 psi Stage 9: 15 bbls gel diesel 9# 20/40 @ 20 BPM, 3390 - 3450 psi Stage 10:15 bbls gel diesel 10# 20/40 @ 20 BPM, 3450 - 4310 psi Stage 11:42 bbls flush @ 20 BPM, 4310 - 4800 psi Underflush 1 bbl. Fluid to Recover: Sand in Zone: Sand in Csg: Average Pressure: 974 bbls 34,000# 20/40 300# 3500 psi Drilling Supervisor January 16, 1987 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-70004 Well: 3Q-12 Field: Kuparuk North Slope, Alaska Survey Date: January 6, 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 Sperrl/-$un/NL Industries, Inc. P.O. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 i N C:. CA1 ....(:!;ECT ]:ON CAi...CtJL.(-~]"EI:I i'~4:2,':!:.. ::ii',~":: !i!: :'). . ~ "/,n .... i:;'iL. .'::., ] i:,l"::: © ,q':i) t:::' (') '::' 1 N 'J::O~ ]. 9 i!J: O,, :i. J. Ft :27/. :/C) iii: ()~ ]. O N .27 .. 6,? ['i; ,:::~ (')7' N :I. ,:':,.~ :2,'.: fi:]: ,'": ,, .[ i'..t .-..;':ii:: ,: :);':J! [:i/ ::':.~ ~ :~:i: J N &'7. O F.: O. 2:3 ;:~ .~", · · ~:::' r'~ 22 ..... ;... .... u ::"!: 2. 7. ',i:i', O E: 1. 10 P-,!2:2. :ii:'i;..' h' :1 . 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V [";!: t:'~ 'T' :[ C A !._ f!:} l.:.'i: ('.:T ~[ (.] N C A t... C IJ L A T E g A L 0 N G C L. O'.'B I..t R E 'TH!:-.i: CAt._L-:UL.A"i'iC;IN F:'ROL':EDI. jRE:S ARE BASED ON 't'HE i_.f!~:;E (.iF THREE EIIIMEI'q:~::IONA£. RA]-)IL.~S OF t:.'-._;!:,'V;7'i'T'JJF([iil ME't"HOD. ];NTERPOL. AI"tEE1 VAL. UE:;~; F'(]R E.2.,,;J.EN t,:'.)00 F::EE"f' FIF' MEA:E;LIF;.:I!.::;D FiEF'TH AIRCO At...ASKA., < L.f PA F;/lj t< i NC. .'}i:i! i:':"T'i"i ANiZ:fr.-IORA(:~[i!] ALASKA O A T' E 0 F S I_1 tR V ti:: Y ..I A 1"4 U A R Y O,'k,, I 'i.;.' :!:-:"7 Ci.(~IMFq.:!TAT t 0N DA]'E .... i(.'~Nt..I?~t:-:,"y' :['2, .1.9:i~',? .... t0~[{.~ I',.!IJP'Iii:ii~EF;: Al-.':. ~'-.'i !") -. '7 0 () ':} ,:':f. i'"" ' /-, ''] i '~("~ 1:::~'T 1< E t.. L Y :[:{~ i l?hi i t',.I (:!~ i:.::'[.. :.. :,,, ..... . .............. O F::'i:ii: i'::.: A T' O F;: -i'"t !7 G i.J [ 1':;,' ..................................................................................................................... I I'.IFERF:ULA][:-L V&i...Ll[.:.::i:i; l:::Ed::;: EVtEt',.I 10() F:'EET Fff:' SIJB-':':;EA DEP'i"H ]]Iq'I'ERF'Ot.._A'I"E:.D k) iq L_ l..I E!!; '.i~; F'(')F~ I:'.'i;VEN 100 FLEET CIF:' SLtB~--SE/~ DEF'TH · ::,L E, -.:,l:.~c.i DE;F'"FH ];N'/ERF'OLgt'T'EEI ~¢~';;:~LI.JI!E'.!.~; F'OF;,' E-"VEN ].C:'O F:'I.~[E"r' OF:: -'1:, '- ...... .. ;;:.':~ii! ('.*O,, O(.'.~ :3 .i 4- ,, :ii!:O N ;i. 2 7 ,, 'i;:'() 1.4 ¥2 ,, 5 ]. :;3 ':;.' C:, C:, ,: C.~ C:,:3,:::: :3 ,, ',i;i:,(:. t'-.i ;i. ,:::, :7ii¢ ,, :3 C:, {..,; :ii;: 'ii;' ,, t!!!; 4. 4 0 ('.~ C.:' ,, ,"', (3 .'".'1 'i "'~,, .3 ¢~:i: J".i '::'(":,,:":, :!jj:,:~, t.,J .... .T (')'? .... .:., -.:"i..I O0 .. C:,,.';;: ,:i-,:';:,,:':', ,, :3'7' i'-.i .;?.?O., ,::'i.,:':l i?..j 'i. 2'7 ,. (.:, '1. .'i. ':;;' ,,-:1,::-, ,.':1. ~i:(':, O., 0 C:, .~:.:;;;~: (),, ]. ,'.':.:, t"..l '.,'? ;::-i¢ ';i: ,, 4. ;~:, 1,4 ]. 4 :i~: ,, ]. 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';;'"()i,-.j .... "::'"" .... '"'" ... ,...., .... ,, ....... .. . .. :, ~ .7, ..t .,::. ,. :.:. ;:-' !!J:;.? C:, C:,,, (:, C; i (':,,-";:, 7"..~ ;i. i'",i 7 :::: f'::;, '7 ?' (..,I :37' .q.,, :J!i: !::; :':.:,:3,:':, .. ~")!":, ' '1 ;,;~: :3 "':::' h.I -7'7,::., ,:", c':, I.,.j "-'"-'"" 4!:, :'ii: '"'"" '""::: ..Z~ ;:-' ,/ : .,.'. ,, ./ ....: ~. ,- , .. ~ _.... . !54-00. (')f."~.. . J. :1. '";';::', .. , ,'.':,7 N :_-'!:2.'i:;;~; . 'TL.--: H 420, :F.: ]. .,...~..'"""':' ...,~-500, O0 ].2:34 .7S N fi:&7 , ('~:'?,.. H 44;2, 7'? .,:..":'":'.~.. ,, 4,7 ANIi]:HO R A(}E '" '~" ........ ARCO AI,...ASKA., ];NC. :3(::! ..... :1.2 C:OMF:'Lt]"A"FIOi',t DATE 1.:'] ....... iF'Al:::: I.::' ,...iAfxliJAF:..'¥ ] /.'"~., :I ,::.:,~::,,7 A i.... A '!ii; i< A .FIA'['E r"lF:' .::, ...i F,, v t:: Y , IANLIARY' 06., 1 'P87 '[N]"ERPOi.,~TED VALLIE'.iii; F'OR EVEN t00 F:'E;ET OF '.!.:.;LIB-'.3EA DEF:'TH ;[ I',tTERF'OLATE';JD V&I...UE:i.:.'; F:'OR :.:.'i;F'EC ;[ ,:'-.~t... :~;IJF;,'VEY F:'r3 ;[ N'TS :[ 3 7 Er ,: :;;;' 0 1 4!5 7,, 3 :ifi: t4 BKB T' H I C K N E i:.'; :!]; VEF;,']" t CAL. ~ 0 R ]; G i N -" ,.:. z. / 7 F N L 2 C:, 6 2 F E L ) !::IFC 1 7 '1' 1 .,:,N RO?E.:. I ) F'F;)ZiH f._iI'qEAF:;,' EX'TRAPF.'JL#'.~1"ION BEL..C)W .'FIE]EF'EST STATIr3N, 2) r_'::OMF'U'T'ER F:'ROGRAM - SF'ERFRY :SUN 'THi.--,..'EE ]'.ilMENSIONAL RADIIJ:E; OF L-'L.IRVATLIRE. DATA CALCLILATiON AND INTERPOI..._AT ~ON D'Y F('ADII_.tS (::iF' CI...IRVATLIRE COMF'UTAT'] ON OA'TE ,J A N U A R Y 1 2 ~ _1. ':.-/::-.:'7 NUMBER AK-.BO--7()O0;~ K!ZI...t_Y BI_.:,H I NG EI...EV. -1580.00 6000.00 STATE OF ALASKA ALAS .... OIL AND GAS CONSERVATION COM,~,,,~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Stimulate [] Plugging [] Perforate [] Pull tubing [] COHPLETE Operation shutdown [] Alter Casing [] Other C~ 2. N~'r~ (~fl ODerator 5. Datum elevation (DF or KB) as'Ka ~ I nc. RKB 60' Feet 3. Address 6. Unit or Property name P.O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 2277' FNL, 2062' FEL, Sec.17, T13N, R9E, UM 7. Well number 3Q-12 At top of productive interval 602' FNL, 1937' FWL, Sec. 17, T13N, R9E, UM At effective depth 515' FNL, 1845' FWL, Sec.17, T13N, R9E, UM At total depth 436' FNL, 1761' FWL, Sec.17, T13N, R9E, UM 8. Approval number 7-29 9. APl number 50-- 029-21677 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 7503 'MD feet Plugs (measured) None feet 6798 'TVD 7294 'MD feet Junk (measured) None 6623 ' TVD feet Casing Length Size Cemented Measured depth Conductor 80 ' 16" 1875# Pol eset 115 'MD Surface 3801' 9-5/8" 900 sx AS Ill & 3838'MD 275 sx Class G Production 7348' 7" 300 sx Class G & 7382'MD 175 sx AS I Perforation depth: measured 7077'MD) 7085'MD~ 7081'MD,~ 7110'-7140'MD true vertical 6443'TVD $ 6450'TVD) 6446'TVD~ 6470 '-6496 'TVD Tubing (size, grade and measured depth) 2-7/8", L-80, tbg w/tail ~ 7009' Packers and SSSV (type and measured depth) HRP-I-SP pkr ~ 6978' & FVL SSSV ~ 1792' True Vertical depth 115'TVD 3779'TVD 6697 ' TVD 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 (Completion Wel 1 Hi story) Daily Report of Well Operations Copies of Logs and Surveys Run)~ G Y RO 1§. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 TitleAssociate Engineer (DANI) SW02/002 Date 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 lenglh of time. On workovers when an official test is not required upon completion, report col/~pletion and represefltative 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 County or Parish ~ State Alaska North Slope Borough I Alaska Field Lease or Unit I Well no. Kuparuk River ADL 25512 I 3Q-12 Auth. or W.O. no. ~ T tie AFE AK1665 I Completion Nordic 1 API 50-029-21677 OperatorARCO Alaska, Inc. [A.R.Co. W. L56.24% Iaband°nmontlc°strT°tal number °f wells (active °r inactive) °n thisIcenter priOrof thist° pluggingwell and Spudded or W.O. begun ]Date ]Hour Prior status if a W.O. Complete I 1/18/87 ! 1700 hrs. Date and depth as of 8:00 a.m. 1/19/87 1/20/87 Complete record for each day reported 7" @ 7382' 7294' PBTD, RIH w/2-7/8" CA 10.0 ppg brine Accept ri~ @ 1700 hrs, 1/18/87. ND tree, NU &tst BOPE to 3000 psi. RU Schl, RIH, perf 7110'-7140' @ 12 SPF/120° phasing & ~ 7077', 7081' & 7085' @ 1SPF/O° phasing. RD Schl. RIH w/2-7/8" CA. 7" @ 7382' 7294' PBTD, RR 6.8 ppg diesel Rn 216 jts, 2-7/8", 6.5#, L-80 EUE 8RD AB-Mod tbg w/SSSV @ 1792', HRP-1-SP Pkr @ 6978', TT @ 7009' Tst tbg to 2500 psi, ann to 2500 psi & SSSV to i000 psi. ND BOPE, NU &tst tree to 250/5000 psi. Displ well w/diesel. RR @ 1615 hrs, 1/19/87. Old TD New TD Released rig Date 1615 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data PB Depth 1/19/87 m.d of rig Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 7244' PBTD Rotary 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 Etfectlve date corrected The/~3ve is correct ITM Si~ ~'~ 7~ /'/.w~ Date -~ , ~5~ ~/! Drilling Supervisor Drilling, Pages 86 and 87, AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. no. DIvlNon of AtlsnflcRIchfleldCompsny Date: ARCO Alaska, Inc Pos! Office L~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 9, 1987 Transmittal # 5909 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. CBL Finals: 3Q-13 1-9-87 6162-8074 3Q-14 1-9-87 6416-8392 3Q-11 1-9-87 5158-7127 3Q-9 1-8-87 7113-7760 3Q-12 1-9-87 5127-7284 3Q-lO 1-8-87 5418-8240 Receipt Acknowledged: DISTRIBUTION: BPAE Chevron (+ sepia) Unocal (+ sepia) NSK L. Johnston "'-"/ .,..,,~ nil & Gas ConS. ~'~ ..... Anchofag~ Mobil (+ sepia) SAPC (+ sepia) Drilling ~~'~~~J,~l~:l ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichfleldCompany ARCO Alaska, In, Post Offic~ _~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 20, 1987 Transmittal # 5891 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Tzansmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Finals: (1 blueline unless otherwise specified) 3Q-12 2" & 5" FDC Raw 12-14-86 5900-7458 ~ 2" & 5" FDC Porosity 12-14-86 5900-7458 2" 5" - ~ & DIL 12-14 86 1000-7484 Cyberlook 12-14-86 6800-7400 3Q-11 2" & 5" FDC Raw 12-20-86 3810-7238 2" & 5" FDC Porosity 12-20-86 3810-7238 ~ 2" & 5" DIL 12-20-86 3810-7264 Cyberlook 12-20-86 6750-7200 3Q-10 2" & 5" FDC Raw 12-27-86 4650-8356 2" & 5" FDC Porosity 12-27-86 4650-8356 "& 5" DIL 12-27-86 4371-8382 berlook 12-27-86 7800-8300 25" Density High Resolution Passes 12-27-86 6678-8223 Receipt Acknowledged: DISTRIBUTION: NSK Drilling L. J6hnston (vendor pkg) Rathmell D & M State (+ sepia) Vault (film) ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASK,-, .)IL AND GAS CONSERVATION COMMIe, SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon C Suspend ~ Operation Shutdown .~ Re-enter suspended well E~ 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, Inc. 60'RKB feet 3. Address 6. Unit or Property name P. O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 7. Well number 2277' FNL, 2062' FEL, Sec. 17, T13N, RgE, UM At top of productive interval 519' FNL, 1862' FWL, Sec. 17, T13N, R9E, UM(Approx) At effective depth 621' .FNL, 1924' FWL, Sec. 17, T13N, RgE, UM(Approx) At total depth 439' FNL, 1732' FWL, Sec. 17, TI3N, RgE, UM(Approx) 30-12 8. Permit number 86-189 9. APl number 50-- 029-21677 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured -~" true vertical 7503 'MD feet Plugs (measured) 6791 ' TV]) feet 7294 'MI) feet Junk (measured) 6617'TVI) feet None None Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" Surface 3801' 9-5/8" Production 7348' 7" Perforation depth: measured None true vertical None Conductor Report not Received 900 sx AS III & 275 sx Class G 300 sx Class G & 175 sx AS I ll5'MD 3838'MD 7382'MD ll5'TVD 3776'TVD 6690'TVD Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Description summaw ofproposal ~ WELL HZSTOR¥ 13. Estimated dateforcommencing operation January, 1987 Detailed operations program BOP sketch ,--' 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~/ Commission Use Only (DAM) SA/192 Date Conditions of approval Approved by Notify commission so representative may witness ~ Plug integrity ~ BOP Test ~ Location clearance Approval No. .~ ~,~=~,~¢_~-,-~'~' by order of Commissioner the commission Date / '/,..~~7 Form 10-403 Rev 12-1-85 Submit in triplicate Well History - Initial Report- Dally Inel~.otione: .PrePare and submit the "Initial Ral~ort" on the first We~esday after a well is spudded or workover operations are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only. District ~ Counly. paris, or borough Alaska ~ ] North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25512 Auth. or W.O. no. {Title AFE AK1665 { Drill DoYon 9 State Alaska Well no. 3Q-12 AP1 50-029-21677 Operator IARCO W.I. ARCO Alaska, Inc. . Spudded or W.O. begun JDato }Hour [ ,or status,f a w.o. Spudded 12/10/86 2300 hrs. Date and depth as of 8:00 a.m. 12/11/86 12/12/86 12/13/86 thru 12/15/86 12/16/86 Complete record for each day reported 56.24% 16" @ 115' 1444', (1329'), Drlg Wt. 9.3, PV 18, YP 25, PH 8.5, WL 13.2, Sol 7 Accept ri~ @ 2000 hfs, 12/10/86. NU diverter sys. Spud @ 2300 hfs, 12/10/86. Drl 12¼" hole to 1444'. 501', .5°, N60.8E, 501 TVD, -32 rs, 1.07N, 1.91E 1020', .7°, N39.7E, 1019.94 TVD, -12 VS, 4.55N, 6.09E 16" @ 115' 3858', (2414'), POOH for csg Wt. 9.4, PV 16, YP 8, PH 9.0, WL 9.2, Sol 7 Drlg from 1444'-2698', CBU, POOH & chg BHA, RIH, ND 2698'-3858', CBU, short trp, Circ hl cln, POOH for 9-5/8" 1488 2615 2952 3269 3650 3783 'MD, .4°, S26.1E, 1487.95TVD, -3.26VS, 4.02N, 10.55E 'MD, 2.0°, S70.SE, 2614.78TVD, -19.14VS, 3.59S, 26.69E 'MD, 6.6°, N13.1W, 2951.20TVD, -11.86VS, 11.22N, 33.48E 'MD, 17.3°, N24.5W, 3260.43TVD, 52.34VS, 76.20N, 13.10E 'MD, 26.9°, N34.0W, 3613.45TVD, 192.97VS, 200.74N, 55.64W 'MD, 30.0°, N33.4W, 3730.39TVD, 256.18VS, 253.49N, 90.80W 9-5/8" @ 3838' 7503', (3645'), Logging Wt. 9.9+, PV 16, YP 8, PH 9.0, WL 4.2, Sol 10 RU & rn 96 jts, 9-5/8", J-55, 36#, BTC csg w/FC @ 3756', FS @ 3838'. Cmt w/900 sx AS III & 275 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. ND diverter, NU & tst BOPE. RIH, DO cmt & flt equip + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 7503', short trip to 5400', spot 60 bbls diesel pill, POOH. RU Schl f/OHL. 4392', 35.7°, N41.OW, 4242.01TVD, 586.52 VS, 516.62N, 290.53W 5497', 35.3°, N38.6W, 5141.01TVD, 1228.50 VS, 1009.73N, 702.37W 6060', 35.4°, N40.1W, 5600.31TVD, 1554.09 VS, 1261.62N, 908.90W 6629', 34.7°, N45.gW, 6066.02 TVD, 1879.43 VS, 1500.0IN, 1131.36W 7503', 33.7°, N45.5W, 6790.77 TVD, 2362.23 VS, 1837.70N, 1485.47W 7" @ 7382' 7503' TD, 7294' PBTD, ND BOPE 10.0 ppg NaC1/NaBr Cont OHL. RIH, make wiper trip, circ, spot 60 bbls diesel pill, POOH. RU & rn 175 jts+ 1 mkr jt, 7", 26#, J-55 BTC csg w/FC @ 7295', FS @ 7382'. Cmt w/100 sx 50/50 Pozz, 4% D-20, .5% D-65 & .2% D-46. M&P 200 sx C1 "G" w/3% KC1, .9% D-123, .3% D-133 & .2% D-46. Displ w/brine, bump plug. ND BOPE. For form prepe/~t~n and distributionS, see Procedure~.Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor 'ARCO Oil and Gas Company Daily Well History-Final Report Inalructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ICounty or Parish /~tate Alaska Alaska North Slope Borough Field ILease or Unit IWell no. Kuparuk River ADL 25512 3Q-12 Auth. or W.O. no. ~ Title AFE AK1665 } Drill Doyon 9 API 50-029-21677 Operator ARCO Alaska, Inc. A.R.Co. W.I. 56.24% Spudded or W.O. begun Date Spudded 12/10/86 Date and depth Complete record for each day reported as of 8:00 a.m. 12/17/86 Iotal number of wells (active or inactive) on this i cst center prior to plugging and bandonment of this well 1 our J Prior status if a W.O. 2300 hrs. I 7" @ 7382' 7294' PBTD, 10.0 ppg NaC1/NaBr ND BOPE, set csg slips, displ top 110' brine & cmt csg. Install seal ssy, NU tree & test. RR @ 0930, 12/16/86. Old TD Released rig 0930 Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data JNew TD PB Depth 7503' TD 7294' PBTD Date Kind of rig 12/16/86 Rotary Type completion (single, dual, etc.) Single I Official reservoir name(s) I Kuparuk Sands ,,, !Well no. Date Reservoir [Producing Interval Oil or gas Test time Production Oil on test Gas per clay Pump size, SPM X length Choke size T.P, !C.P. Water % GOR Gravity Allowable Effective date corrected The/j~ve is c0rrect IDT/ ITM S~4:~'~..~ ~ ~//~9~" 7 Drilling Supervisor sFe°; f~/omprep a'~ced u r e s~'a nnu'aal? ds ed ic~: r(~ nbUlt ,0o, ~:) -'/ ' Drilling, Pages 86 and 87. ARCO Alas~,a, In,'~ Post Office: ~ 100360 .~. Anchorage, AlasKa 99510-0360 Telephone 907 276 1215 RE_~3PR~ TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 ~anchora~e AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. DATE December 23, 1986 ~RANSM~.~.~ ~ 5860 Please acknowledge receipt and 3Q-14 OH LIS /ape + Listing 372100 12-3-86 3Q-13 OH LIS Tape + Listing #72114 12-9-86 3Qrl?. OH LIS Tape + Listing 7,,~o3~ 12-14-86 Receipt Acknowledged~ Distribution: ~ ~- I1 We.here__ State of Alaska ARCO Al~mk~. December 5, 1986 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-12 ARCO Alaska, Inc. Permit No. 86-189 Sur. Loc. 2277'FNL, 2062'FEL, Sec. 17, T13N, R9E, UM. Btmhole Loc. 393'FNL, 1765'FI. TL, Sec. 17, T13N, R9E, LR,~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indenmify 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. !.~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. f_~ez~?~V tru!M.~urs, / ~ C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COI~,fISSION 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 u,._ AND GAS CONSERVATION CO~,,,¢IISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill 'l~" Redrill lb. Type of well. Exploratory [] Stratigraphic Test Fl Development Oil 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 23' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25512 ALK 2553 4. Location of well at surface 7. Unit or propertY, Name 11. Type BOnd(see 20 AAC 25.025) 2277'FNL, 2062'FEL, Sec.17, T13N, R9E, UN Kuparuk River Unit Statewide At top of productive interval 8. Well nu .mber Number 519'FNL, 1862'FWL, Sec.17, T13N, R9E, UM 3Q-12 #8088-26-27 , At total depth 9. Approximate spud date Amount 393'FNL, 1765'FWL, Sec.17, T13N, R9E, UM 12/10/86 '.,./'¢ $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 3Q-13 7485 'MD 393' ¢ Total depth feet 25' ¢ surface feeti 2560 f6791 'TVD~ feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth2685 feet Maximum hole angle 34 0 Maximum surface 2223 psig At total depth (TVD) 3273 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2~" !6" 62.5# H-~:O Weld 80' ~5' ~5' !!5' !!5' ±200 cf HF-F'EW 77c, nv ~"lnc~ C, hlcnrl 8-1/2" 7" 26.0# J-55 BTC 7h51' 36' 3~' 7485' 6791' 200 sx (]la~s Gfminimum HF-E[W TOC 5 O' ab.ov; top of K..~.par~k lg. To be completed for Redrill, Re-entry, and Deepen Operations. Present well aondition 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 ~-;1 ? Surface Intermediate Production '...:ii';.i~; 0 i!; i986 pth Perforation de : measured true vertical 20. Attachments Fil(n.g fee~¢' Property plat [] BOP Sketch ~ Diverter Sketch ~ Drilling program~ ..... ,' '- Drilling fluid program~!(~. Time'vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requiremen, ts .~.]~.... 21. I hereby certifj(_,that the foreg,,ging is true and correct to the best of my knowledge S'gned / ?/ ~.¢¢,//_~.~.~. ~2~,, TitleRegi°nal Drilling Engineer Date ~'" Commission Use Only (RHE) PD/020 ~ 5' '7'~' ~ I 50-- c~"~*,. -'~' 4; ~ "t 12/05/86 for other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required L-] Yes ~' No .Hydrogen sulfide measures [] Yes [] No Directional survey required ~ Yes El No Other:Required work~'d~,u~7~E3~ . 5M; [] IOM; [] 15M by order of Approved by ~ ',, ~'~~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 ' Subm ~ trir)linnt~ / 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 6 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices wiii 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. 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. LWK5/ih 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 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drillin$ 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. 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. LWK5/ih KUPARUK RI VER UNIT 20" DIVERTER SCHEMATIC i.I I.. DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10" OUTLETS 5. 10" HCR BALL VALVES W/10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION, 6. 20" 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REOUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION 2 IL · · 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, ,~, ~.... ii~ _:. i ~ ~ DO NOT SHUT IN UNDER ANY CIRCUMSTANCES JG I1-3-86 < <, ,.> DIAGRAM #1 13-5/8" 5000 PSI RSRRA BOP STACK I. 16" - 2000 PSI TAN<CO STARTING HEAD 2. II" - 3000 PSI CASING HEAD 3. Ii" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRILLING SPOOL W/CHOKE KILL LI~ES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/PIPE R/~ ON TOP, BLIND RAMS ON BOTTCM. '7. 13-5/8" - 5000 PSI i I 2 ACCUNIJLATOR CAPACITY TEST I. CHEOK ~ FILL ACCU~TOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSU~ THAT ACCL~TOR PRESSURE IS 3000 PSI WITH 1500 PSI DO~TREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTA~EOIISLY A~D RECCRD THE TI~E At~) PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING ~ OFF. 4. RECORD ON NADC REPORT, THE ACCEPTABLE LClIE~ LIMIT IS 45 SE~ CLOSING TIhE A~D 1200 PSI RE]V~INING 15-5/8" BOP STACK TEST I. FILL-BOP STACK ~ CHOKE MANIFCLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL LOCK DOAN SCR~ IN WELLHEAD ARE FLLLY RETRACTED. SEAT TEST PLUG IN ~ELLFE_AD WITH RUNNING JT AI~ RUN IN LOCK[~ SCREWS. 3. CLOSE /e~IJLAR PREVENTER ~ MANUAL KILL /~ CHOKE LI~E VALVES ADJACENT TO BOP STACK, ALL OTFER VALVES AND CHOKES SHOULD BE OPEN. 4. PRESSURE UP TO 250 PSI AND HOLD FOR I0 MIN. IN- CREASE PRESSURE TO 3000 PSI ~ HOLD FOR I0 MIN. BLEED PRESSURE TO 0 PSI. 5. OPEN AhlqlJLAR PREVENTER A~D MANUAL KILL mN] CHOKE LIkE VALVES. CLOSE TOP PIPE RAMS AI~ HCR VALVES ON KILL AND CHOKE LIkES. 6. TEST TO 250 PSI ~ 3000 PSI AS IN STEP 4. '7. CONTI~ TESTING ALL VALVES, LIkES, AND Q-K3<ES WITH A 250 PSI LOW AN) 3000 PSI HIGH. TEST AS IN STEP 4. ,DO NOT PRESSURE TEST ANY Ct-E3KE THAT IS NOT A FU~L CLOSING POSITIVE SEAL CHOKE, O~LY FUNCTION TEST CHOKES THAT DO NOT FULLY CLOSE. 8. OPEN TOP PIPE RAMS A~D CLOSE BOTTCM PIPE RAMS. TEST BOTTCM PIPE RAMS TO 250 PSI A4%D 3000 PSI, 9. OPEN BOTTCM PIPE RAMS, BACK OUT RUht~ING JT AND PULL OUT OF HOLE. I0. CLOSE BLIND RAMS AND TEST TO 250 PSI AND 3000 PSI. II. OPEN BLIND RAMS AND RETRIEVE TEST PLUG. MAKE SURE MANIFOLD ~ LIkES ARE FULL OF NON-FREEZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STANDPIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, AND INSIDE BOP TO 250 PSI AN) 3000 PSI. 13. RECORD TEST INF(]~VtATION ON BLOWOUT PREVENTER TEST FORM, SION, AND SEI~D TO DRILLING SUPERVISOR. 14. PERFC~M COvPLETE BOPE TEST AFTER NIPPLING UP AND WEEKLY THEREAFTER FUNCTIONALLY OPERATE BOPE DAILY. 510084001 REV. 2 MAY 15,1985 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weis, hr 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 AP1 20 10-20 pR 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drillin~ 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. 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. LWK5 / ih GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blowout 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. SHALE SHAKERS DEOASSERI HUD CLEANER STIR ~ STIR --.-t~. STIR / i ! CENTRIFU6[ TYPICAL HUD SYSTEH SCHEHATIC LWK4 / ih ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 19, 1986 Mr. C. V. Chatterton Commissioner 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. you have any questions, please call me at 263-4944. Si ncerely, d. Gruber Associate Engineer JG/dmr GRU1/44 Enclosure If ^r~r',c~ ~l~ct,~, In,,- i,~ n ~lh,~irliarv of AtlanlicRichfieldCompany Jlllttlt 8 9 I? I$ VICINITY MAP S~IL[ ~ I" · 2 MILES ALL WELLS LOCATED IN SEC. 17, TI3N, R9E, UMIAT MERIDIAN. I 16,025,07:3.23 2 16'025'867'50 $ 16,025,861.28 4 16,025,055.29 16'025'849'$6 16,o2 ,845.$7 7 16,025,837.44 8 Is,025, 8~51.43 9 16,025, 8~.~ JO 16,02~, ~7.25 12 J6,02~, 7~.~ ~6,025~ 789.31 16,o25, 783.47 15 J6,025, ?77.44 16 J6,025, 771.~ ;Ps" 'X' 515, 959.92 515, 984.20 S 16,008.42 516,032.59 516,056.99 §16,061.28 §16,105.64 §16,129.72 516,202.58 516,226.&?. 516,251.42 516, 275.30 SI6,299.52 516, 323.80 516,348.20 516,37'~ .$1 LATITUDE 70° 2 8' 54.758" 70° 28'54.701" 70° 28' 54.639" 70° 28' 54.500" 700 28' 54.52 I" 700 28' 54.462" 70° 28'54. 403** 7o° 28' 54. :343' 70° 28' 54. 165" 70° 28' 54. 103" 700 20' 54.044' 700 28' 53.9~7" 70" 28' 53.925" 70° 28' 5:5. es~ 70o 28' 53.6o9" 70° 28' 53.740" NOT~S: I. Al./.. COORC~ATES ArK A.S.R, ZONE 4. 2.AL.L DISTJdlCET 9H0WN dd~ 3.ELEITIONI All B.P, ILI. L. 4. REF. FIELD ~ LII-I6, Pogot 21-22. 5. O. G. ELEVATIONS FROM ,... IELL . ASSOCIATES. 6.HORIZONTAL ~ITIONS ~D CXll 3Q C(~~ t ~/ ~NTS PER LHD I ASSOC. LONGITUDE 149°52' 10.512" 149° 52' 09.79~*' 14g° 52' 09.0~" 149° 52'08.376" 149° 52'07.656" 149° 52'06.944"! 141° 52' 06.220" 1490 52'05.520" 149O52'05.378" 141e 52'02.665" 141e 52'01.942" Iql152'0l. 240" 14"1o 52'00. 520" 141e 51' 59.814 140° 5 I' 59. 007" 1490 51'58. :~98" ~ DIst. F.N.L. [ tt J ' ! _ (I '1 ~t l DIIt. EE.L: iO.O E'I : 2199' 2377' 17. I 21.7 220~' 2362' 17.1 21.7 2211' 232e' 17. I 21,? 2217' 2304' 17,2 21,e 2223' 22~' 17, Z 2 2~' 2255' 17, ~ 2~ D 22~' 2231' 17.3 2241' 220~ 17.4 2~9' 2134' 17.5 22~ 22~' 2110' 17.3 22~ 2271' 20~* 17.5 22~' 2~* 17~ 2 2203' 2037' 17.5 21 .O 220~ 201 ~ 17~ 21.8 22~ 1909' 17~ 21.9 230J' 19S5' 17.5 21~ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED Atto LICENSED TO PRAC- TICE LANO SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS ANO OTHER DETAILS ARE CORRECT AS OF D.S.$Q ,, WELL, CONDUCTOR ASBUILT _ Illl [ I I I I I DATE, il/lO/N j NSK 6. ii (2) Loc (2 thru-8) ~' CHF/X LIST FOR NE~ WElL pERMITS DATE o.9' (10 /md 135 / 12. 13. ~ 22) (5) BOPE ~z)-~ /X~S~/ (23 thru ~28) (29 thl:u 31) (6) Add: Is the permit fee attached .......................................... YES NO ~ 14. 15. 16. 17. 18. 19. 20. 21. 22. 2. Is well ko 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 w~llbore plat included ............ ,...~ ' 7. Is operator the only affected party ................................. ~ 8. Can pennit be approved before fifteen-day wait ...................... 23. 24. 25. 26. 27. 28. For 29. 30. 31. 32. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number · Is conductor string provided ..................... ................... ~z Will surface casing protect fresh water zones ....................... .~ .,, Is enough cenmnt used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or production strings ... ~ .., Will cenmnt cover all known productive horizons ..................... ~ Will all casing give adequate safety in collapse, tension and b st Is this well to be kicked off from an existing wellbore ....... .t~..... ~ ~f Is' old wellbore aband~t procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ /~( Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to 3000 ,, psig .. Does the choke manifold comply w/AP1 P~-53 (May 84) .................. Is the presence of. H2S 'gas probable ................................. C~ology~: EngiDee~ing: rev: 07/18/86 fi. Ol! 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' ,, Additional requirements ............................................. INITIAL GEO, UNIT ON/OFF POOL CLASS STA2~S AREA NO. SHORE , ,. ,., Additional Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding informatiOn, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special 'effort has been made to chronologically organize this category of information. VEqI:ZC~TZ~N LZ ST Z~]S LVP 010,~102 V~i¢:!C~TiiSN ~.ZSTI,.'<G c~GE i S E R V Z ;T.. E N .,z. !,,! E : E C: i T 9~'T~ :.96/1 33~',!M~NTS : tli~:R~,kY ;:= /NFC~MAT!,ON .001 : ;'.~ : ~ ,:< C ¢3 A t ,-;; :<. ,~, .'- >'! '-. · 00 ..... u $1 .~.., C ..,r"' .=: .... ' ,.,~00 uOu OO .: OA:, Z: .,'~ i,,,: i 3 X O r., 0 ,~"' '} 3 004 .0 .':, :5 r C T: ! 7 ,3 L"' :3, .30 :"',~ 00 2 0 5 5 t U :'~: b ,2; T '~ l, t :.;"0 '-- 006 00 ,"",., .~,12'" 065 :,~ E ~! C "XT r ~',aT S UN iT T Y ~ f C aT E S- Z E C 7 D E LV~ OlO.kO£ V=RiF!C~TiC~''~ L= ELD : STATE = ALASKA JOB NU',!BER ~.T ACC: 72123 '"<:JN ~ON.E, DATE L(]GGED: l~, DEC 86 _JP: T H~,LSTEAD 'ASiNG )~NSiT'f tISCGSZTY :LUiC' LOSS ::' N TRY ~LOCKS SPEClFiC~TIO,N BLCCKS SERv'IC~ Sf~:'VlCf U¢,~!T ;E?T FT FLU Lr, "' "'L L 51 O0 :3{3 ,.,0 i i 1 I CC3E 7~ APl A)! APl FiLl SIZE SPL TY~ CLASS !400 gOO'; O0 0 O ~ 1 2n 31 C '~ ¢ iZO 44 0 ~ 4 1 P'~CCES$ (OCTAL) 0 000000'3 O00 O00 0C333000000000 LVP OlO.h02 VERiF:iCaTi]N LiSTiNG P,aGE 4 ?' ;;" D 6 T A ...... -,--,,- 'qPHi -93 · 55 Z 5 5 R ~1.3574 DP~i -999.2500 EPT ? 7aO0.O000 -147.7500 Gq 2.47!7 ~303.00n=. .. SFLu - 157. ~ 7: 0 31.0547 -999.2500 ErsT 7 2_00 · :3 O C 0 S'- L j - i .53 · 0 ,."', C. 95 ~ £.~f4~ l:,<.- ' 39.4531 bP~l 910 31 3 31C 28,9 359 420 OOC 2.S625 I04.87;0 0.0f96 1!.23C5 .i.8639 I0~.3750 0.0596 3.1372 105.7500 '~ ~77' zv.7;7C 4.i434 $7.8750 0.3591 5.614~ 3.5~19 91.7375 zs. ,.,4':.9 47.716~ ..... · 2537 0 03 i'" Z*_~. 546 i Gl Oi 01 O! 02 Ol O! 90 3! 30 Ol NC N' iLF: N C N L l L ~ NChL lt2 "'~T kC hS ~. C ,~,: i 2.1743 104.~750 3.3925 1973.0000 2.1743 104.8750 3.3828 1973.0000 2.3535 136.7500 ~ 145 192!.0000 3.i250 97.8750 2.SO0~ 91.5375 3.3027 56 2.7227 ~ C, ': 0 · 5 S 63 iL~ CALl FCNL iL~ C~tl FCN' C~iLi FCNL "LM CALl =CNL C.&Li FC ~,iL iLM CaLl FC'< L 9000000 O00000O 9000000 0000000 ~,000000 9900900 OOO0000 OOOO000 O000OO0 0900000 ,~OOOnO0 09 00 00 00 00 00 0O O0 00 00 00 O0 O0 O0 O0 OO O0 O0 O0 O0 O0 O0 000 000 000 000 000 000 O00 000 000 000 2.2825 8.3125 3.5254 559.50.30 2.2799 8.3125 3.5,i54 559.5000 2.4218 8.6250 3.6895 520.5003 3.4245 2.894~ 753.0000 3.!457 8.5933 3.4277 20.0837 a.3935 2.9539 ~.PT 7039.3:70J S=L'~ 2.J153 't-~ i.75c~ '' !" i.'S323 LV? elOod02 V':~i~-iL".,~'TiJ::, LiSTZt4~b P~GE 5 - 999.2500 6900 OOr~O 6~00~0000 - 123. 0625 ~4.775~ -999,2500 5 700.00 e 0 - I Z 4.587 ~ 2.. 395~ · - 999. · 5 500.0 O00 -i?L. 2500 ~ 0.966 3 - 999.2 ~ O 0 S~O0.0'.]00 i. 5156 34.5705 ~O0.OOOO - 13 ~ · 5 ~ C u 2, -117 ~ ~u;3 - 1'~7.12~ :~ :? 9102 5 2 00. 0,} 00 -!51,!25- :3. l 5. ltO5 ~12.657f 19.9 5 9 l ~'. ,~ 1 ~ .Z l~O . ;000 0.0 Z 59 15. 3730 3. i 5~. 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