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195-082
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2T-26 KUPARUK RIV UNIT 2T-26 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 2T-26 50-103-20223-00-00 195-082-0 W SPT 5712 1950820 1500 2625 2625 2625 2625 640 710 710 700 4YRTST P Adam Earl 6/21/2025 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2T-26 Inspection Date: Tubing OA Packer Depth 1090 1810 1780 1775IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625073931 BBL Pumped:0.6 BBL Returned:0.6 Tuesday, July 22, 2025 Page 1 of 1 MEMORANDUM TO: Jim Reggper �% . j •7i`� 6 z�( P.I. Supervisor ��%l FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 22, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2T-26 KUPARUK RIV UNIT 2T-26 Src: Inspector Reviewed By: P. 1. Supry� Comm Well Name KUPARUK RIV UNIT 2T-26 API Well Number 50-103-20223-00-00 Inspector Name: Brian Bixby Permit Number: 195-082-0 Inspection Date: 6/18/2021 Insp Num: mitBDB210619061722 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-26 'TypeInj W TVD 5712 - Tubing 2650 2650 2650, 2640- PTD 1950820 " Type Test SPT est psi 1500 ' IA 1190 1920 1880- 1870 BBL Pumped: 0.7 BBL Returned: 0.7 - OA 500 _ 570 - 570 - 570' Interval 4YRTST p/I+ P Notes: Tuesday, June 22, 2021 Page 1 of 1 . • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday,June 17, 2018 9:16 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 2T-26 (PTD 195-082) Update 6-17-18 Attachments: 2T-26 90 day TIO trend 6-17-18.JPG Chris, KRU WAG injector 2T-26 (PTD 195-082) is coming to the end of the extended monitor period on gas injection. During the extended monitor period the IA pressure stabilized and did not exhibit signs of communication. COPA intends to return the well to 'normal'status at this time. If any suspect annular pressure anomalies are observed in the future they will be reported at that time. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. JUN 2 0 colb Office phone: (907)659-7224 WEA 1 • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday, May 18, 2018 10:01 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 2T-26 (PTD 195-082) Update 5-18-18 Attachments: 2T-26 90 day TIO trend 5-18-18.JPG Chris, KRU WAG injector 2T-26 (PTD 195-082) is coming to the end of the monitor period on gas injection. The IA pressure has show a slight increase, but appears to be tracking along with injection rate and temperature increase. COPA intends to extend the monitor period an additional 30 days to assure a valid determination is made. At the conclusion of the monitor period an update with any required paperwork will be provided. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 4111IZELLS TEAM scams' MAY 2 22M • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Tuesday, April 3, 2018 8:05 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 2T-26 (PTD 195-082) Update 4-3-18 Attachments: 2T-26 90 day TIO trend 43-18.JPG Chris, KRU WAG injector 2T-26 (PTD 195-082) is coming to the end of the extended monitor period on water injection. The annular pressures have remained stable with no signs of communication. The plan at this time is to leave the well on water injection and perform a high pressure MITIA(hedging against a possible TxIA waiver). The well will then be WAG'd to gas for a 30 day monitor on gas injection. If the well exhibits signs of communication while on gas injection an application for Administrative Approval will be submitted. If no signs of communication are exhibited the well may be returned to normal status. At the conclusion of the diagnostic and monitor period an update with any required paperwork will be provided. A 90 day TIO is attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 WELLS on ocanAlips SCANNED 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday, March 4, 2018 1:16 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: KRU injector 2T-26 (PTD 195-082) Update 3-4-18 Attachments: 2T-26 90 day TIO 3-4-18.JPG Chris, 2T-26 is nearing the end of its 30-day monitor while on water injection. Following the circ-out of the backside fluid,the IA is no longer exhibiting the same repressurization as was observed when initially reported. However,the well appears to be taking a bit longer than normal in reaching stabilization. Therefore to ensure that there is full integrity while on water injection,the well will be monitored for an additional 30 days before making any conclusions. Please let us know if you disagree with the plan forward. Attached is an updated 90 day TIO plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7224 CW From: NSK Well Integrity Supv CPF1 and 2 Sent: Friday,January 19, 2018 3:35 PM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: RE: KRU injector 2T-26(PTD 195-082) Update 1-19-18 Chris, Since being shut in on December 15, 2T-26's IA has no longer exhibited an IA repressurization. The current speculation is that there was significant gas entrainment that was being liberated with increased thermal input and/or a deep trapped gas bubble was coming to surface,causing the continued repressurization even when the well was on water injection. The well was circulated with fresh clean fluid to remove any residual gas in the annulus and a passing MITIA was performed yesterday. CPAI intends to return the well to water injection for a 30 day monitor period. At the conclusion of the monitor, an update will be provided with path forward. If indications of communication resume during the monitor,the well will be shut in and freeze protected and further diagnostics will be planned. Please let us know if you disagree with the path forward. Attached is an updated 90 day TIO plot and the recent MITIA data. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 1 • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday,January 19, 2018 3:35 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: KRU injector 2T-26 (PTD 195-082) Update 1-19-18 Attachments: MIT KRU 2T-26 diagnostic MIT 1-18-18.xlsx;2T-26 90 day TIO 1-19-18.JPG Chris, Since being shut in on December 15, 2T-26's IA has no longer exhibited an IA repressurization. The current speculation is that there was significant gas entrainment that was being liberated with increased thermal input and/or a deep trapped gas bubble was coming to surface,causing the continued repressurization even when the well was on water injection. The well was circulated with fresh clean fluid to remove any residual gas in the annulus and a passing MITIA was performed yesterday. CPAI intends to return the well to water injection for a 30 day monitor period. At the conclusion of the monitor,an update will be provided with path forward. If indications of communication resume during the monitor,the well will be shut in and freeze protected and further diagnostics will be planned. Please let us know if you disagree with the path forward. Attached is an updated 90 day TIO plot and the recent MITIA data. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. g� ��� Desk Phone (907)659-7224 NSK Well Integrity Supv CPF1 and 2 Sent: Fri. , December 15,2017 2:32 PM To:Wallace, is D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyle .Tyler.Senden@conocophillips.com>; NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips. > Subject: KRU injector 2T-26 (x,195-082) Update Chris, KRU WAG injector 2T-26 (PTD 195-082)was reporte• •n November 23,2017 for a suspect IA pressure anomaly subsequent the well having been WAG'd to water injects• A passing MIT-IA and passing MIT-OA were achieved after which a series of bleeds were performed to de-gas the IA. Th- , ell was placed on a monitor period during which the IA pressure continued to increase despite additional bleeds. The plan : this time is to shut the well in as soon as possible and continue diagnostics in attempt to locate and repair a leak if possib Any required paperwork for continued injection or corrective action will be submitted at the appropriate time. A 911 .y TIO trend, and 10-426's for the aforementioned MITs are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons • . Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday, December 15, 2017 2:32 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: KRU injector 2T-26 (PTD 195-082) Update Attachments: 2T-26 90 day TIO trend 12-15-17.JPG; MIT KRU 2T-26 diagnostic MITs 11-25-17.xlsx Chris, KRU WAG injector 2T-26(PTD 195-082)was reported on November 23, 2017 for a suspect IA pressure anomaly subsequent the well having been WAG'd to water injection. A passing MIT-IA and passing MIT-OA were achieved after which a series of bleeds were performed to de-gas the IA. The well was placed on a monitor period during which the IA pressure continued to increase despite additional bleeds. The plan at this time is to shut the well in as soon as possible and continue diagnostics in attempt to locate and repair a leak if possible. Any required paperwork for continued injection or corrective action will be submitted at the appropriate time. A 90 day TIO trend, and 10-426's for the aforementioned MITs are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 AWELLS TEAM Cmocxips 1 • S Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Thursday, November 23, 2017 8:50 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of IA pressure anomaly 2T-26 (PTD 195-0Q2) 11-23-17 Attachments: 2T-26 90 day TIO 11-23-17.JPG; 2T-26 schematic.pdf Chris, KRU WAG injector 2T-26 (PTD 195-082) is displaying an IA pressure anomaly. There have been repeated bleeds performed since being WAG'ed to water on November 10, 2017. Prior to the WAG,the well had been on gas injection since June 27, 2017. We will begin the initial suite of DHD diagnostics to include MIT, packoff testing and bleeding as necessary as soon as possible. 2T-26 will be placed on a 30 day monitor on water injection once the initial diagnostics are complete, assuming a passing MIT. If there are indications that gas has migrated over to the IA via a gas-only leak (deep FL,significant gas presence etc),following the water monitor,the well will be WAG'ed back to gas injection for an additional 30 day monitor to confirm or deny the presence of a gas-only leak. As always, if the MIT fails,the well will be shut in and freeze protected as soon as possible with follow-up well intervention work as necessary. Please let us know if you disagree with the path forward. Attached are the schematic and 90 day TIO plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 Mobile Phone (907)943-0170 SCANNED k er 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggDATE: Thursday,June 15,2017 P.LSupervisor )Se et 6.( °I(7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-26 FROM: Lou Laubenstein KUPARUK RIV UNIT 2T-26 Petroleum Inspector Src: Inspector Reviewed By:�n P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-26API Well Number 50-103-20223-00-00 Inspector Name: Lou Laubenstein Permit Number: 195-082-0 Inspection Date: 6/5/2017 Insp Num: mitLOL170607152857 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-26 • Type Inj W TVD 5712 Tubing 2590 2590 - 2600 - 2590 - PTD 1950820 ' Type Test SPT Test psi 1500 IA 970 2000 1970 - 1970 - BBL Pumped: 1.1 BBL Returned: 1.3 - OA 30 130 _ 130 130 Interval 4YRTST P/F P Notes: SCANNED `,;EP I 3 201? Thursday,June 15,2017 Page 1 of 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~',~- ~.~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Diann~Nathan Lowell Isl [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 03,2013 TO: Jim Regg �e„ P.I.Supervisor ' ( "(` ( i SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-26 FROM: Lou Grimaldi KUPARUK RIV UNIT 2T-26 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-26 API Well Number 50-103-20223-00-00 Inspector Name: Lou Grimaldi Permit Number: 195-082-0 Inspection Date: 6/1/2013 Insp Num: mitLG130601152752 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-26 Type Inj W 'TVD 5712 H IA 1240 2010 1991 1994 - PTD ! 1950820 Type Test SPT psi si 1500 OA 530 605 605 605 Inter 4YRTST P 2600 2600 -_ 2620 P/F ',Tubing � 2620 zv2o Notes: .83 bbl's diesel pumped, 1.1 bbl's returned.Good solid test,crew well prepared.Flowline in serious bind,unsupported with heavy snow load. SCANNED FEB 2 0 2014 Monday,June 03,2013 Page 1 of 1 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 1, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: 5 ~~~ ~°I a ~ _ a~ ~~C~iVED f"'' zo n r,~~ ~, ~~asK~ (~ ~ Gas C~ Cp-issior~ ~~4~~~«=~r;~g~ 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 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 21St. The corrosion inhibitor/sealant was pumped July 30tH, 31St 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off r Report of Sundry Operations (10-404) Kuparuk Field Date 8/01/10 ~R ~K ~T pnn Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 26-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7/31/2010 2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7/31/2010 2K-20 50103201200000 1891180 10" n/a 10" n/a 2 7/31!2010 2K-23 50103201250000 1900140 SF n/a 18" n/a 2.6 7/31/2010 2K-24 50103201220000 1891300 SF n/a 18" n/a 2.6 7/31/2010 2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010 2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7/30/2010 2T-20 50103202150000 1950290 SF n/a 23" n/a 2.6 7/30/2010 2T-21 50103202120000 1950130 SF n/a 21" n/a 3.4 7/30/2010 2T-26 501A3202230000 1950820 SF n/a 27" n/a 4.3 7/30/2010 2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7/30/2010 2T-30 50103202190000 1950570 SF n/a 30" n/a 6 7/30/2010 2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7!30/2010 2T-36 50103202280000 1951020 SF 0.40 12" 7/21/2010 2.6 7/30/2010 2T-39 50103203920000 2011830 30" 0.54 14" 7/21/2010 4.3 7/30/2010 2T-201 50103202300000 1951220 60" 1.57 32" 7/21/2010 7.7 7/30/2010 2T-204 50103203270000 2000160 SF n/a 24" n/a 5.1 7/31/2010 2T-209 50103202810000 1982430 40" 1.20 19" 7/21/2010 4.8 7/31/2010 2T-218 50103204490000 2030170 31" 0.73 9" 7/21/2010 2.6 7/31/2010 2T-220 50103202830000 1982530 38" 0.49 19" 7/21/2010 5.1 7/31/2010 • MEMORANDUM TO: Jim Regg ~~(`l ~ ~l/a/ ~/ P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-26 KUPARUK RIV UNIT 2T-26 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: KUPARUK RIV UNIT 2T-26 API Well Number: 50-103-20223-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ090608125109 Permit Number: 195-082-0 ~ Inspection Date: 6/1/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-2~Type Inj. ~w T-VD s~1s /' IA slo ~ zolo •- ~ ' ~ ' ~ ~ 190 190 '~~ 1950820 PT 150 1500 / S0 P.T.D _ TypeTest ~_ ~ est ps_~ A ~ 4YRTST P ~ TUbin ~ 2625 1 2600 ~ P/F Interval ___, g I I ~ 200 200 I ~ 265 2650 ___l_ _ ____ Notes• 1.6 BBLS diesel pumped, 1 well inspected; no exceptions noted. ;f 'f' -; qt ry~E;. '~ ;'u ..:~.ri ' ,E_ c; ~ 1.11: ~, Wednesday, June 10, 2009 Page 1 of I MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Ketlh¡D7 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-26 KUPARUK RIV UNIT 2T-26 \~5/ffò'ð FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :f8F-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2T-26 API Well Number: 50-103-20223-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070603144947 Permit Number: 195-082-0 Inspection Date: 6/2/2007 ./ ReI Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-26 Type Inj. N TVD I 5713 IA I 140 2550 2510 2510 I P.T.D 1950820 TypeTest SPT Test psi I 1500 OA I 0 0 0 0 Interval 4YRTST P/F P ;/ Tubing I 2040 2040 2040 2040 Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. /' sCANNED JUN ,~ 1 2DD7 Wednesday, June 06, 2007 Page 1 of 1 MEMORANDUM TO: Randy Ruedrich Commissioner THRU: Jim Regg P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission b~ DATE: June 14, 2003 ,.1t~,~,~ ,, SUBJECT: Mechanical Integrity Tests ~:...~.,iL;L Conoco/Phillips Kuparuk River Field 2T Pad FROM: John Crisp Petroleum Inspector NON- CONFIDENTIAL Kuparuk River Unit Packer Depth Pretest Initial 15 Min. 30 Min. P.T.D.I 1860960ITypetestl P ]TestpsiI 3000 ]Casing] 1150 ] 3080 ] 3050 ] 3040 ] P/F ] ~ Notes: OA 160 psi. pretest & 170 psi. during test. 3.5 BBL. Pumped, WellI 2T-la IType,nj.I s I T.v.D. I ,~,o ]Tubing] 2400 I ~4oo I 2,oo 12400 Ilntervall 4 P.T.D.] 1950170ITypetest] P ]Testpsi] 3000 ]Casing] 1800 I 2970 I 2950 I 2940 I P/F ] ~ Notes: OA 760 psi. pretest & 900 psi. during test. 2 BBL. Pumped. ] We,I 2T.26 IT~,pe,,j.I s I T.V.D. I~ I~u~,,~l ~o I~o I ~o I~o I,,terv~,l 4 I P.T.D.I 1950820ITypetestl P ]TestpsiI 3000 ] CasingI 1020 I 3010 I 3000 I 3000 I P/F I P I Notes: OA 0 psi. during test. 2 BBL. Pumped. I WellI 2T-28 ]Type I s I T.V.D. I~0 I Tubing] 2120 12120 I 2120 I~0 Ilnterval] 4 P.T.D.] 1950920IType I P ]Testpsi] 3000 ]Casing] 1340 I 3050 I 3000 I 2980 ] P/F ] P Notes: OA 0 psi. during Well] 2T-29 ]Type P.T.D.I 1950750 ]Type Notes: OA 0 psi. during test test. 3 BBL, Pumped. ,,i.I ~ I T.v.o. I~ I Tubingl~O I~0 I ~0 I~0 ]Interval] 4 test] P ]Testpsi] 3000 ]Casing] 240 I 2950] 2925] 2910] P/F ] P test. 5.4 BBL. Pumped. j. . Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details I travded to C/P's Kuparuk River Field to witness 4 year MIT's. No failures witnessed. Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed' 5 Number of Failures: O Attachments: Total Time during tests: 4 hrs. cc: MIT report form 5/12/00 L.G. ,AUG 0 ~ 2003 2003-0614_M IT_KRU_2T-29_jc.xIs 6/24/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuld KRU/2T 06/14/03 Sauvageau/Brake - APC John Cdsp Well 12T-'I 0 P.T.D. It860960 Notes: Well 12T-t 8 P.T.D. I1950170 Notes: Well 12T-26 P.T.D,11950820 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. I ITypeInj I Sp I T.V.D. 15771 I Tubing I 25501 25501 25501 25501 'ntervall i~ I Type Test Test psi I 1500 I Casing I 11501 30801 30501 30401 P/F I Typelnj I Sp I T.V.D. 15760 I Tubing I 24001 24001 24001 240011ntervall ~I TypeTest Test psiI 15oo I Casing I 18001 29701 295°1 29401 P/F ITypelnj I ~ IT'V'D' 15713 I Tubing I ~3301 23~01 ~3~01 ~3~011ntervall ~ Type Test Test psiI 15oo I Casing I 10201 30101 30001 30001 P/F Well 12T-28 P.T.D. 11950920 Notes: TypeTest Test psiI 1500 I Casing I 13401 3050.1 30001 29801 P/F Well 12T-29 P.T.D, I1950750 Notes: Well 12T-36 P.T~D~It951020 Notes: TypeTest Test psiI 1500 I Casing I 2401 29501 29251 29101 P/F ITypeInj I pS I T.V.D. 15736 I Tubing I 12501 12501 12501 12001 'nterva'l 4P Type Test mestpsiI 1500 I CasingI 13001 30501 30001 30001 P/F P.T,D. I1951220 Type Test Test psiI 1500 I Casingl 13501 29501 29201 28751 P/F Notes: Carried MIT out for one hour Pressure at 45 min 1100/2820 1 hr 1100/2800 Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 05/19/02 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test 2003-0614_M IT_K RU_2T-10_-18 -26 -28 -29 -36_-201 .xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) 6/25/2003 KRU 4 yr MIT's 2K & 2T Subject: KRU 4 yr MIT's 2K & 2T Date: Sun, 15 Jun 2003 16:23:23 -0800 From: "NSK Problem Well Supv" <nl 617@conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, jim_regg~admin.state.ak.us, tom_maunder~admin.state.ak.us CC: "nl 617" <n1617~conocophillips.com> Tom, Bob, Jim, Attached are the 4 yr MIT's for injection wells on 2K and 2T. Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224 (See attached file: MIT KRU 2T 06-14-03.xls) (See attached file: MIT KRU 2K 06-14-03.xls) ~MIT KRU 2T 06-14-03.xls Name: MIT KRU 2T 06-14-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 ~MIT KRU 2K 06-14-03.xls Type: EXCEL File (application/msexcel) I Encoding: base64 i! 1 of I 6/25/2003 1:45 PM [) A "i" A q' D A '1' A_,,F' L U S 683~ >/'T 3696-~-92~0 J,4W!3, (:IR S I.. i I:~ ',' ~ -,. ,' [:. Y :~;?'i 21 92 i 0 A iq A D R :£ I,... L. 95" 082 ',:.;;IJl.~Vr.r.,.!y ~ J ~: 1 9. 133 AN AD R :[, L, L 9 5 -- 082 95 '08~. © S IJ Iq.:: V E Y ,SBT SI.. :J: i,'i ,3 95 "'08,,., © ~.~ 0 0 ~, 9 0 3 7 Page ~ I Date; 0?/:08/9? UN DATE ..... RECVD 09/06/95 os/1 08/29/95 08/29/95 os/1 s/ss 09/06/95 08/~ 8/95 JO /.~0'/ ~ COI,~PLETIOH DATE ~/i'0~q3 / /(~/~.,q~/ A I'" C' W :::: 'J 'l < .... · yes ~ And r'e<.e~ved? yes~ .~ ¥ I: :::: I', :.; a m p 1 ::: ::', r' e q u '¥ r' e d o ~.,,/e'i I <.:,::)~"cd: ,/as ._Analys'~'s :: descr"ip:'ion r"ece'ived? y~ _esl. c; i-equYr" ( .... .' C ,S, H i,'l ~' N T ::; ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 25, 1995 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T-26 (Permit No. 95-82) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 2T- 26. If there are any questions, please call 265-6206. Sincerely, M. Zang ~ni-- Supervisor Kuparuk Drill Site Development MZ/skad STATE OF ALASKA ALAS,.,-, OIL AND GAS CONSERVATION COMM,~.-.:ION WELL COMPLEIION OR RECOMPLI::'I'ION REPORT AND LOG I Status of Well Classification of Service Well OIL E~] GAS E~] SUSPENDED F'"'"J ABANDONED [] SERVICE r~ classification chan~led to Water Injector 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-82 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20223 4 Location of well at surface 9 Unit or Lease Name · ~ ~. · ~. :.~ :, 478' FSL, 556' FWL, Sec. 1, T11 N, RSE, UM '- ';f.~,,~?'i.~?10t.;, ~ , ..,,,~,,,,,. ' ~ Kuparuk River At Top Producing Interval ! ~:,.,.vf? ' !!¢,,,a,&~~ 10 Well Number 1075' FSL, 1380' FWL, Sec. 36, T12N, RSE, U~ 2T-26 -~'" -' 11 Field and Pool i j, ~,-~.~ At Total Depth I! 1352' FSI~ 1412' FWL, Sec. 36, T12N, R8E, UM!.;'- ................ i KUPARUK RIVER ''~ ~'"' ,,,=~q~,~,~.~.¢,,r ~.~.~. .,. .- : 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Kuparuk River Oil Pool " RKB 41' Pad 81' ADL 25548 ALK 2662 '.- 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of CompletiOns June 9, 1995 June 15, 1995 06-Sep-95 (peri'd)I NA feet MSL 1 " 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directio.nal Survey 120 Depth where sSsv set 21 Thickness of permafrost 9210' MD & 6089' 'I'VD 9085' M D & 5992' TVD YES xL~ NO L.JI NA feet MD = 1380' ss APPROX 22 Type Electdc or Other Logs Run = GR/CCL/USIT/CBT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VV'I- GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 Surf. 121' 24" 240 sx AS I 9.625" 40.0# L-80 Surf. 3696' 12.25" 770 sx AS III Lead, 580 sx Class G Tail 7" 26.0# L-80 Surf. 9174' 8.5" 212 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) 3.5" 8748' 8717' 8830'-8870'MD 4 spf 5797'- 5827'TVD 8888' - 8908' MD 4 spf 5840' - 5855' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 8914' - 8922' MD 4 spf 5860' - 5865' TVD DEPTH INTERVAL(MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) September 16, 1995 (injecting)I Water Injector Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ¢ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE Ie 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~.- -., ?-, -- .., {~ .... Form 10-407 Submit in duplicate Rev. 7-1-80 ~INUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8775' 5755' Bottom Kuparuk C 8801' 5775' Top Kuparuk A 8813' 5784' Bottom Kuparuk A 8987' 591 5' 31. LIST OF ATTACHMENTS Directional Survey, Daily Drilling History 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ' Form 10-407 Date:10/05/95 Page: 1 ARCO Alaska Inc. DAILY DRILLING REPORT WELL:2T-26 RIG:PARKER 245 WI: 55% SECURITY:0 WELLID: AK8237 AFE: AK8237 TYPE:DEV AFE EST:$ 1354M/ 1760M AREA/CNTY:NORTH SLOPE STATE:AK API NUMBER:50-103-20223 FIELD: KUPARUKRIVER SPUD: START COMP: FINAL: 06/09/95 (1) TD: 121'(121) SUPV:RLM 06/10/95 (2) TD: 3710' (3589) SUPV: DWG/DCB 06/11/95 (3) TD: 3844'(134) SUPV:rLM 06/12/95 (4) TD: 5099' (1255) SUPV:rLM 06/13/95 (5) TD: 7580' (2481) SUPV:rLM 06/14/95 (6) TD: 8611'(1031) SUPV:JT 06/15/95 (7) TD: 9150' (539) SUPV: JT 06/16/95 (8) TD: 9210' ( 60) SUPV: JT 06/17/95 ( 9) TD: 9174'( 0) SUPV:JT MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 FUNCTION TEST DIVERTER Move rig from 2T-29 to 2T-26. Accept rig at 0400 hfs 6/9/95. Nipple up diverter system. DAILY:S19,000 CUM:S19,000 ETD:SO EFC:$1,372,900 MW: 10.1 TOH Drilling from 121' - 3710' . DAILY: $90,612 CUM: $109,612 PV/YP: 25/24 ETD:SO APIWL: 0.0 EFC: $1,463,512 MW: 9.6 PV/YP: 29/34 APIWL: 0.0 DRILLING Ran 9-5/8" casing to 3696'. Cement casing. CIP at 1613 6/10/95. Test BOPE. Test casing. Directional drill 8.5" hole from 3720' to 3844' DAILY:S213,225 CUM:$322,837 ETD:SO EFC:$1,676,737 MW: 9.8 PV/YP: 27/20 APIWL: 0.0 POOH FOR WASHOUT Directional drill 8.5" hole from 3844' to 5099'. DAILY:S82,319 CUM:$405,156 ETD:SO EFC:$1,759,056 MW: 9.6 PV/YP: 17/16 APIWL: 0.0 DRILLING Directional drill 8.5" hole from 5099' to 7580'. DAILY:S75,623 CUM:$480,779 ETD:S0 EFC:$1,834,679 MW: 10.9 POOH F/BIT #4 Drilled from 7580 to 8611' DAILY:S109,552 CUM:$590,33i PV/YP: 26/17 ETD:SO APIWL: 4.6 EFC: $1,944,231 MW: 10.9 DRILLING Drilled to 9150'. DAILY:S75,140 CUM:$665,471 PV/YP: 21/16 ETD:SO APIWL: 4.6 EFC: $2,019,371 MW: 10.9 PV/YP: 24/15 APIWL: 4.4 CEMENTING 7" PRODUCTION CASING Drilling from 9150' to 9210'. Run 7" casing. Cement casing. DAILY:S73,398 CUM:$738,869 ETD:SO EFC:$2,092,769 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MOVED TO 2T-22 Cement 7" casing. CIP @ 0700 hrs. Install packoff, test. Freeze protect annulus. Release rig 1630 hfs 6/16/95. DAILY:S199,500 CUM:$938,369 ETD:SO EFC:$2,292,269 Date: 10/05/95 Page: 2 ARCO Alaska Inc. DAILY DRILLING REPORT REMEDIAL AND COMPLETION OPERATIONS WELL: 2T-26 WELLID: AK8237 AREA/CNTY: FIELD: SPUD: AFE: AK8237 START COMP: RIG:NORDIC WI: 0% SECURITY:0 TYPE:DEV AFE EST:$ 1354M/ 1760M STATE: API NUMBER: FINAL: 08/27/95 (10) TD: 9210' PB: 9085' SUPV:DCL 08/28/95 (11) TD: 9210' PB: 9085' SUPV:DCL RACK AND TALLY TBG/RD SCH MW: 8.6 SEAWATER Move rig from 2T-23 to 2T-26. Function test BOPE. Test casing. Set packer at 8700' DAILY: $22,896 CUM: $961,265 ETD'SO EFC: $2,315,165 RIG RELEASED MW: 0.0 Run in hole with 3-1/2" completion assembly. Freeze protect well. Test tree and packoff. Release rig @ 0200 hfs 8/28/95. DAILY:S136,751 CUM:$1,098,016 ETD:SO EFC: $2,451,916 9/6/95 Perf 'A' sand interval 8830'- 8870', 8888'- 8908', and 8914'- 8922', using 2- 1/8" EJ with BH charges, 4 spf, 0° phasing. To establish injectivity, inject 20 bbls of diesel into well @ 1.4 bpm and 3000 psi pump pressure. End of WellSummary for Well:AK8237 PAGE NOt ********* ANADRILL ********** ********* SCHLUMBERGER *********~ APl WELL APC AE~237 *********** SURVEY ANALYSIS *********** COMPANY ARCO ALASKA WELL NAME 2T-26 LOCATION I ~UPARUK LOCATION 2 ALASKA 'DAT£: 09-JUN-95 MAGNETIC D~CLINATION 28,47 GRID CONU£RG~NCE ANGLE WELL NUMBER 0 ***** .**** AHADRILL ************** SURVEY ANALYSIS ************* CIRCULAR ARC 2T-26 MD ?VD INC CH~ CUMINC CH~ ft ft deg deg 121,0 376,3 465,9 558,2 649,? 121,00 0,00 376,30 0,40 465,88 0,07 558,22 649,86 0,82 I RAT~ AZM CHG CUMAZM CH~ deg/1OOft deg deg TURN RATE .. deg/lgOft 0,00 0,00 0,00 0.00 0,00 0,40 0,16 79,07' 79,07 30,97 0,47 0,08 6.08 85,15 6,7? 0,65 0,19 7,38 92,53 7,9? 1,46 0,89 -I7,52 75,01 -19,12 CLOSURE TOOL FAC£ DLS DLSRT - ft deQ deg/lOOft deq/lOOft**2 0,00 0,00 0,00 0,00 -0,84 0,00 0,16 0,06 -1,50 35,35 0,09 0,07 -2,38 25,50 0,21 0,12 0,00 0,00 0,95 0,81 739,7 829,7 920,3 1011,2 1101,2 739,52 2,42 829,12 2,98 918,78 3,14 1008,05 1,54 1096,13 0,92 3,88 2,70 -17,27 57,74 -19,24 6,86 3,31 0,87 58,61 0,97 10,01 3,47 -11,83 46,76 -13,05 11,55 1,ZO -3,3! 43,47 -3,64 12,47 1,03 -3,54 39,93 -3,93 -7,36 27,12 2,81 2,08 -13,87 1,85 3,31 0,55 -23,04 34,85 3,94 0,70 -33,32 23,48 1,83 2,33 -3,98 30,36 1,31 0,57 1194,6 1289,0 1382,9 1474,8 1569,2 1187,12 1,11 1278,57 1,39 1368,85 1.88 1456,Z0 0,72 1545,96 3,03 13,58 1,19 -4,81 35,11 "5.15 14,97 1,48 -7,05 28,06 -7,47 16,~ 2,01 -5,00 23,06 -5,33 i7,57 0,78 '5,72 17.34 '6,22 20,60 3,21 -10,40 6,95 -11,01 -54,17 46,78 1,66 0,37 -63,50 54.74 2.36 0,74 -71,31 36,47 2,48 0,13 -77,15 6?,83 2,00 0,52 -43.76 40,35 4,81 2,98 1664,2 1758,~ 1851,9 1945,1 2039,1 1633,53 4,32 1717,97 3,69 1798,68 2,62 1877,12 2,94 1952,90 4,07 24,92 4,55 -2,86 4,09 -3,01 28.61 3.90 3,66 7,75 3,87 31.22 2,8! 1.65 9.40 1,77 34,16 3,15 0,41 9,8t 0,44 38,23 4,33 -0,09 ?,72 -0,10 -77,79 15,67 4,69 0,12 -76,52 25,70 ' 4,27 0,44 -77,22 18,17 2,95 1,42 -78,87 4,49 3,16 0,23 -79,30 53,31 4,33 1,25 2!34,0 2226,5 2319,3 2412,8 2505,9 2025,27 4.14 2091,65 3,60 2153,85 3,87 2211,46 4.20 2264,03 3,18 42,37 4,36 1,22 I0,94 45.97 3,8? 0,48 11.42 49.84 4.17 -0,49 10,93 54.04 4,49 -I,*12 9,81 57,22 3,42 -1,60 8,21 1,29 -83,62 11,29 4,44 0,12 0,52 -87,50 5,46 3,90 0,58 -0,53 -91o61 5,54 4,19 0,30 -1,20 -94,96 12,18 4,59 0,43 -1,72 -80,82 0,82 3,70 0,96 2692,4 2881,0 3068,? 3255.4 3442,1 2361,74 2,36 2457,36 -0,07 2552,28 0,31 2646,77 -0,52 2741,76 0,24 59,57 1,26 -1,15 7,06 -0,62 59,51 -0,03 -0,48 6.58 -0,25 59,81 0,16 -0,40 6,18 -0,21 59,30 -0,28 0,30 6,48 0,I6 59+54 0,13 -0,83 5,66 -0,44 -96,33 22,94 1,37 1,25 -93,71 99,10 0,22 0,6I -89,86 48.35 0,24 0,01 -85,91 153,21 0,31 0,04 -96,65 23,00 0,40 0.05 3616,1 2829,57 0,31 3727,9 2886,31 -0,70 3822,3 2934,97 -0,34 3926,0 2988,27 0,48 4014,0 3033,35 -0.2! 59,85 0,18 2,74 8,39 1,57 59,15 -0,63 -0,09 8.30 -0,08 58,81 -0,36 0,09 8,39 0,10 59,29 0,46 -3,33 5,06 -3,21 59,08 -0,24 -0,89 4,18 -1,01 -79,35 83,15 1,37 0,55 -80,37 173,35 0,63 0,66 -81,22 166,17 0,37 0,28 -79,65 81,29 2,79 2,34 -81,22 71,34 0,90 2,16 4107,2 3081,47 -0,27 4200,4 3131,05 -1.92 4294,4 3181,43 1,32 4382,0 3227,32 0,39 4475,4 3277,9I -2,74 58,81 -0,29 1,41 5,5? 1,52 56,90 -2,06 1,26 6,85 1,36 58,22 1,41 -0,90 5.96 58,6I 0,44 -0,51 5,45 -0.58 55,86 -2,94 3,58 9,03 3,83 -71,55 102,85 1,33 0,46 -69,45 151,19 2,36 1,10 -67,60 29,99 1,62 0,7~ -64,95 48.61 0,66 1,09 -75,54 105,52 4,36 3,95 *****, .**** ANAl)RILL ************** SURVEY ANALYSIS ************* CIRCULAR ARC M£TNOI)******** 27-26 MD TVD INC CHG CUMINC CH~ I RATE AZM CHGCUMAZM CHG TURN RATE ft ft deg deg deg/lOOft deg deg deg/lOOft CLOSURE TOOL FACE DLS DLSRT ft deg deg/lOOft deg/lOOft**2 4850,6 3484,27 1.53 57,39 0.41 0,55 9,58 0,15 -72,76 16.84 0,43 1,05 5131,5 3637,15 -0.72 56,67 -0.26 -0,23' 9.35 -0,08 -79,85 165,24 0.27 0.06 5411,4 3791,25 *0,15 56,51 -0,06 -1,55 7,80 -0,55 -83,25 97,22 0,47 0,07 5693,0 3947,21 -0,27 56,24 °0,10 -0.17 7,63 -0,06 -83,14 153,38 0.I1 0,13 5972,6 4102,63 -0.04 56.20 -0,02 0.24 7.87 0,09 -64,22 133,31 0,07 0.01 6255,6 4252,35 3,72 59,92 1,32 2.07 9.94 0,73 -88,16 25,83 1,45 0.4? 6629,5 4450,79 -3.91 56.0I -I,05 -7,17 2,78 -1o92 -80,95 124,63 1,93 0,13 6910,2 4608,23 -0.24 55.77 -0,09 0,34 3,12 0,12 -61,52 131,06 0,13 0.64 7188.0 4761,54 1.48 57,25 0,53 4,13 7.25 1,49 -51,26 67,88 1,35 0,44 7468,3 4916,40 -1.58 55.67 -0,56 -1,43 5,82 -0.51 -83,18 I02,57 0,71 0,23 7748,3 5077,50 -1,56 54,11 -0.56 -0,59 5.22 --0,21 -37,51 162,96 0,58 0,04 7932.1 5185,16 0.06 54.17 0,04 -0,33 4,89 -0,18 -30,54 76,50 0,15 0,24 8027,9 5241.14 0.10 54.27 0,10 -1,28 3.61 -1,34 -25,82 84,85 1,09 0,98 8119.5 5295,86 -1,86 52,41 -2,03 2,19 5,80 2,39 -21,91 137,26 2,79 1,85 8214,9 5355,79 -2,73 49,68 -2,86 1,33 7,13 1,39 -46,37 143,35 3,06 0,29 8304,3 5415,31 -2,84 46,84 -3,18 0,05 7,18 0.06 -19,56 179,34 3,18 0.13 8399,0 5480,36 -0,37 46,47 -0,39 -0,42 6,76 -0,45 -18,63 140,52 ' 0,51 2,82 8487,7 5543,18 -3,26 43,21 -3.68 0,12 6,88 0.14 -17,62 178,51 3,68 3,58 8678,9 5684.31 -1,50 41.71 -0,78 3,15 10,03 1,65 -19,18 126,33 1,36 1,21 8770,0 5751,67 1.13 42.84 1,24 -1,52 8,51 -1.67 -20,24 159,72 1,67 0.34 8955.8 5890,95 -2,81 ' 40.03 -1,51 -1.98 6,53 ' -1,07 -20.38 155,72 1,67 0,00 9133.7 6029,48 -2,36 37.67 -1,33 -0,57 5,95 -0,32 -17,48 171,54 1,34 0,18 LAST SURVEY IS PROJECTED 9210,0 6089.90 0.00 37.67 0,00 0,00 5,95 0,00 -16,02 0,00 0.00 1.76 RECEIVED *******~* ~HLUMB~RO~ ******~** *********************************************************** APl YELL ~ 50-!03-~0££3- O0 ~r, T~'~ CO~PA.~' ARCO ALAS)~A ~ELL NAIVE 2T-~6 LOCATION 1 XUPARU?, :OCATION .2 ALAS.KA MAGNE~Iu D~CL!NAT!ON GRiD ~ONV~,~C~~,~ o., O0 bA~E: 09-JUN-~5 WELL ~]UMBER ~uu~i~u~: ~(N/-~ O,~ AZIMUTH..FROM ROTARY TABLE TO ,~r~nu~,: TS. TIE iN POINT(TIP) : M;~RED ~Er'~H 121,00 TRUE PERT DEPTH 121,00 INCLINATION 0,00 AZIMUTH ~,~ O0 LATITUDE(N/-S) 0,00 DEPARTURE(~z-'''~, ~ n~nO~ OEP(E/-~) NICI FiLME __ PAGE t40, 2 - - 2T-26 ***w********* ANADRILL SURVEY CALCULATIONS ************* CIRCULAR ARC ME?HOB******** w-~noKn !NT~RVAL V~!6~ TARGET ~A~ION AZIMUTH LATITUDE ft ft ft ft deo deo ft 1£1,~.~ ~,~ 12i,00 0.~0 0,00 0,00 0,00 376,30 255,3 376,30 0,2? 0,40 79,07 0,17 558,23 92,3 558,22 0,59 0,&5 92,53 0,27 DEPARTUR~ DISF'LAC~M~NT at ~/-W ft ft 1,55 1,57 2,44 2,46 4,09 4,13 AZIMUTH de.??, O,O0 ?9,07 ~0,49 83,73 deg/ lOOft 0,00 0,16 0,09 0,2! 0,?5 920,30 !011,17 1i01,22 90,0 739,52 ~,~ 49 3,88 57,74 2,47 ~',77 8,15 72,37 2,81 829,I2 8,~. == 6,86 58,61 6.90 14.94 16,45 55,22 3.21 916,78 !8,38 I0,0i 46,78 15,1I 25,30 29,47 57,15 3,94 1008,05 31.70 11,55 43,47 27,12 37,31 46,13 53,99 1,83 !096,13 47,45 12,47 39,93 41,12 49,75 64,55 50,43 1,31 1!94,62 !288,98 1382,85 !56?,25 93,4 94,4 ?4,4 I]87,!2. ,~'~,,~ =~.~3,58 35,11 57,82 ~.,.0~ ~ ~5,17 1278,57 oz.?9 :4,~7 ?~ ' .o,06 77,64 74,64 107,70 1368,85 II!,49 !6,85 23,06 100,87 85.67 132,34 l=a~ ?X 168,71 20,60 ~,q~ 156,50 101.30 186.42 47,2~ 43,87 40,34 32,91 1,86 2,36 2,48 2,00 4,81 1664,22 !758,81 185!,93 1945,15 2039,07 ?5,0 94,6 93,I 93,2 ?3,9 1633,53 I717,97 1798,68 ~,12 205,40 24,72 4,09 193,05 247,94 28,61 7,75 235,38 294,37 31,22 9,40 281,29 344,6? 34,16 9,81 330,92 400,1I 38,:o ~" 9 , 72 385,58 104,74 219,64 28,48 4,69 109,22 259,48 24,89 4,27 124,57 353,59 20,63 3,16 133,97 408.19 !$',16 4,33 2123,77 2228,54 2317,34 2412,80 2505,9! 94,? 2025,27 461,41 42,37 10,74 445,74 145,00 468,?2 92,6 20?1,65 525,78 45,~7 11,42 509,21 i57,51 533,01 ?2,8 2!53,85 5?4,50 49.84 I0.93 576,75 170,84 801,52 93,5 2211,46 667,99 54,04 ?,81 649,12 184,06 674,71 93,1 2264,03 744,6I 57,22 8,21 725,01 196.06 751,05 18,01 17,19 16,50 !5,83 15,13 4,44 3,90 4,19 4,59 3.70 2381,00 3068,?1 3255,39 3442,12 I~6,5 !88,6 !86,5 186,7 2361,74 ~45/.36 2552,28 2646,77 2741,76 903,60 59,57 7,06 882,39 1066,18 59,51 6,58 1042,84 1228,30 59,81 6,18 1205,01 1389,03 59,30 6.48 1364,80 1549,71 59,54 5,66 1524,65 217,i5 908,72 13,83 1,37 236,45 1070,29 12,76 0,22 254,47 !231,59 11,92 0,24 272,20 1291,6fl 11,2~ 0,31 289,19 1551,84 10,74 0,40 3616,12 07,'7, ¥2 3822,34 3925,9& 4013,9,.4 i74,0 111.8 ?4,4 190.0 88,0 2829,57 2~86,31 2934,77 2988,27 3033 ~ 1699,91 57,85 8,39 1673,74 1796,23 59,15 8,30 1769,05 1877,15 5~,8I 8,39 1849,11 1965,98 59,29 5,06 !937,34 2041,44 59,08 4,18 2012,67 307,57 1701,76 !0,41 1,37 321,55 1798,03 10,30 0,63 333,29 1878.?0 10,22 0,37 343,,v =n 1967,5e. 10,06 2,79 349,79 2042,84 9,86 0,90 4107,25 4200,44 4381,96 4475,43 ?3,3 93,2 93,9 87,8 93,5 3081,47 J~I,05 3181,43 3277,91 212i,26 58,81 5,59 2092,30 2200,13 56,?0 3,85 2170,73 2279,37 58,22 5,96 2249,50 2353,94 .38,61 ~,45 2323,75 2432,51 55,86 9,03 2401,70 356,59 2122,47 3~5,13.. ~01,~o 373,97 2280,37 381,38 2254,84 391,24 2433,36 9,67 9,55 9,44 9,32 9,25 1,33 2,36 0,66 4,36 PAGE MEASURED INTERVAL VERTICAL DEPTH D£PTH ft it it 4S50,59 375,2 3484,27 5131,5! 280,9 3637,15 5411,o~= 279.8 3791,25 5693,04 281,7 3947,21 5972,=" ,5 ~ln2 ~o 279 , ~ ,63 6629.49 69!0.24 7188,00 7468,?~ 7748,35 7932 '~ 8304,27 8399.04 8487.65 8678.94 8769,98 283,0 4252,35 373,9 4450,79 280,8 4608,23 277,8 4761,54 280,3 4916,40 5077,50 95,7 5241,14 91.6 5295,86 95,3 5355,79 89.4 5415,3i 94,8 5480.36 88,6 5543,18 19!,3 5684,31 91,0 5751,67 8955,77 !85,8 5890,95 9133,67 177,9 6029,48 LAST SURVEY !S PROJECT£B 9210.00 76,3 6089.90 ************* ANADRILL ************** SURVEY ~l r~ ~nNc ************* CIRCULAR ARC METHOD******** TARGET STATION AZIMUTH LATITUDE SECTION iNCLN, N/-S ft ~eo deo ft 2745,68 57,39 '9,58 2710,86 2981,25 5,5,67 9,35 2943,34 ~', "~ s' ~ 7.80 '~114,c:9 3449,38 56,24 7,03 3406,75 qaA1,73 =' 20 7,=* o6o6,°~' 3921,82 .,,~° 92 9,94 ~874,21 4238,29 56,01 2,78 4188,7~ 4469,93 55,77 :~,12 4~9n o. 4701,26 57,Z5 7,.~ ~ 4651,53 4934.80 55,67 5,82 4883,60 51l" 54 ox ,.,o,73 ,11 5,~; 5i11,63 5312,51 54,17 4,89 5259,99 090,03 ~4,27 ~,61 33a7,44 5463,43 52,41 5,80 5410,71 5537,st.. 49,68 ~,= 13 5484,38 5604,26 46,64 7,18 5550,57 5673,17 46,47 6,76 5618,97 ;===,64 43.2i 6,88 5681,01 5864,73 41,71 10,03 5808,72 5925,95 42,84 ~,51 5869" 40.03 6,53 599!,02 37,o/ .,~. . 6207,05 37,67 5.95 6148,34 DEPARTURE DISPLACEMENT at AZIMUTH ft ft deo 441,88 2746,64 9.26 480.63 2982,32 9.27 ~1~ '= ..... ".22 546,94 3450,38 9,12 ~7 97 ~,8,..: 3652,67 9,03 ,>~.,54 3922,3! q,03 651,01 4239.06 8,83 '~ 35 o.~z.96 4470, 8,53 683.95 470i.54 710,56 4935,02 8,28 732,61 5163,86 8,16 745,74 5312,59 8,07 751,50 5390,09 8,0! 757,5! 5463,48 7,97 774,15 5604,29 7,94 782,51 5673,20 7,93 789~92 5735,66 7,92 =~,85 5~64,76 7,93 313,71 5925,98 7,?4 834,85 6048,91 7,93 ~.~ 6160,45 7,?0 4,,?? , :,Zv/,07 deo/ iOOft 0,43 0,27 0,47 0,11 0,07 1,45 0,13 1,35 0,71 0,58 0,15 2,79 3.06 3,18 0,51 3,68 1,36 1,67 1,67 1,34 0 9/6/95 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'I-rN: Sherrie Well .~'~q Job # Log Description NO. 9700 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) Date BL LIS RF Sepia DIR MWD Tape 2T-26 95284 SLIM GR 95061 5 I I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATEA..~asI~a 0ii & Gas to,~s, ARCO Alaska, Inc. Date: August 25, 1995 Transmittal #: 9291 RETURN TO: ARCO Alaska, Inc. Attn: Bdan Hebert Kuparuk Records Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. return one signed co~y of this transmittal. t' ~--c~~'- ~ 2A- 18--~-'~~ .... /' Directional Survey Please acknowledge receipt and AK7621 ~~__.~-22 ~ ~:-. O ~,(~ Directional Survey 5/19/95 AK8213 ~ '~-j._, ~ ' Directional Survey 6/23/95 AK8173 ~: ~ Directional Survey 6/9/95 AK8237 ~(~ ~o~?.~ Directional Survey 7/2/95 AK9229 ~ ~ Directional Survey 5/31/95 AK8157 ~ ~q~ -~.2~T.53.1_~ Directional Survey 7/11/95 AK8181 .~~'~ .--,- . ~ Dire,ctional Survey ,L~/}~t95~ AK8253 ,'" Ack on 'wledaed: ~'~/~.z.~.-"l / ,,J"'~ ~"'/,- Date: 5/18/95 Mr. Vernon E. Pringle, Jr. DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 :::C:l~arry Grant (2 copies),. 3001 Porcupine Dr. Anchorage, AK 99501 ARCO Alaska, Inc. Date: August 18, 1995 Transmittal #: 9287 RETURN TO: ARCO Alaska, inc. ATTN: Brian Hebert Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. USIT 8/3/95 7400-9037 Cement Bond Log (CBT) USIT Cement Bond Log (CBT) USIT Cement Bond Log (CBT) 8/3/95 7400-9013 8/4/95 10746-10794 8/4/95 9300-10732 8/4/95 9000-10427 8/4/95 9000-10403 RECEIVED //~' ~/; ' aska 0il & Gas Cens. Commission Anchorage DISTRIBUTION: Sharon AIIsup-Drake DS Development ATO-1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Erickson/Zuspan NSK Central Files NSK-box 69 ARCO Alaska, Inc. Date: August 11, 1995 Transmittal #: 9285 RETURN TO: ARCO Alaska, Inc. Attn: Brian Hebert Kuparuk Records Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. Please acknowledge receipt and return one signed copy of this transmittal. t,.I ,~/,. O~ °~ 2A- 18 Sub-Surface Directional Survey SUi.' ~',,,-.~,'.,,-..-, ~:r--~:__...i ~,~ o~1./ 2A-28 SurveySUb-SurfaceDirectional 2T-22 Sub-Surface Directional Survey Sub-Surface Directional ~".O'( .~TM Survey ~" '"---(~'3~' 2T-29 Sub-Surface Directional Survey ~ ¢.,.0~fl 2T-31Receipt ,Sub-SurfaCesurve.~ Directional Acknowledged;~ ..~ ~ DISTRIBUTIO :N~ / ' Mr. Vernon E. Pringle, Jr. DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 5/18~95 AK 7621 ~ AK P~-43 7/2/95 AK 9229 6/23/95 AK 8173 6/9/95 AK 8237 5/31/95 AK 8157 7/11/95 /~~1 V~.O Date; 4L/ 5 ~nChorage. C~**/~ Larw Grant (2 copies) 3001 Porcupine Dr. Anchorage, AK 99501 MEMORANDUM TO' THRU: Blair Wondzell, //~z P. I. Supervisor FROM: Bobby Foster, Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 10, 1995 FILE NO: ABXIFJCD:doc SUBJECT: BOPE Test - Parker 245 ARCO - KRU - 2T-26 PTD # 95-0082 Kuparuk River Field Saturday, June 10, 1995: I traveled this date to ARCO's KRU DS 2T-26 and witnessed the initial BOPE test. As the attached AOGCC BOPE Test report shows there were no failures~ The choke manifold had been tested before I arrived on location and the results had been chaded and looked OK. i informed John Crisp, Parker toolpusher and Bobby Morrison, ARCO rep., to call the inspector on duty to notify us if the manifold was to be pretested so we can witness if possi~ble or to wait until the regular test. The rig was clean and all equipment seemed to be in good working order. The location was clean and all related drilling equipment was properly stored. Summary: I/the initial BOPE test on Parker rig 245 drilling ARCO's KRU well 2T-26 - test time 1.5 hours - no failures. Attachment:: AB×IFJCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9.625" Test: Initial X Workover: PARKER Rig No. 245 PTD# ARCO Rep.: 2T-26 Rig Rep.: Set @ 3,696' Location: Sec. Weekly Other 95-0082 DATE: 6/10/95 Rig Ph.# 659-7670 BOBBY MORRISON JOHN CRISP 1 T. 11N R. 8E Meridian U VlISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. 1 Well Sign OK Drl. Rig OK Hazard Sec. OK Test Pressure P/F 300/3,000 P 1 300/3,000 P 1 300/3,000 P 1 300/3,000 P 1 300~,000 P 1 300/3,000 P 2 300/3,000 P N/A MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES TEST DATA FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 3OO/3,OOO P 1 300/3,000 P I 300~,000 P 1 300/3,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 300/3,000 NOTE 30O/3,OOO Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 6 @ 2200 3,000 [ P 1,700 P minutes 25 sec. minutes 24 sec. YES Remote: YES Psig. Numberof Failures: 0 ,Test Hrs.: 1.5 Hours. Number of valves tested 8 Repair Or R'eplaCemen{'°:f~i~ieci':'::: Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at: I 279-1433 REMARKS: NOTE: The choke manifold had been tested before I arrived on location. The results were charted and looked OK and was not retested. I informed John Crisp and Bobby Morrison to call and inspector if the choke manifold was to be pretested so we could witness the test if possiable. Distribution: odg-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER FI-021L (Rev. 12/94) ABXIFJCD.XLS TO: David Johj3~, Chairman/ THRU- Blair Wondzell g~ P. I. Supervisor FROM' Bobby Foster,~'~~;f Petroleum Inspector' Alaska Oil and Gas Conservation Commission DATE: June 9, 1995 FILE NO' EBXIFICD:doc SUBJECT: Diverter Installation Inspection ARCO - KRU - 2T-26 - RIG245 PTD# 95-0082 Kuparuk River Field Friday, June 9, 1995: I traveled this date to ARCO's 2T-26 being drilled by Parker rig 245 and inspected the diverter system. ':l'he rig had spudded in before I arrived on the location and I did a visual inspection of the diverter system, the system had been installed properly with vent line extending out to a safe area and had been tied down very good. All of the related equipment - automatic knife valve, hydraulic lines and accumulator unit - seemed to be in good working order, i read the tour report and found that the test had been logged and the test of the gas detectors had also been logged on the report. Summary:. I inspected the diverter system on Parker rig 245 drilling ARCO's 2T-26 for correct instalation. Attachment:: EBXlFiCD.XLS Drlg Contractor: Operator: Well Name: Location: Sec. STATE OF ALASKA '' ALASKA L~IL AND GAS CONSERVATION COMM. ~ .,ION Diverter Systems Inspection Report Parker Drilling Arco KRU 2T-26 1 T. 11N R. Operation: Rig No. Oper. Rep.: Rig Rep.: 8E Development 245 PTD # Date: 6/9/95 X Exploratory: 95-0082 Rig Ph. # 659 - 7670 John Crisp Merdian Bobby, Morrison Umiat MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK Reserve Pit: N/A Well Sign: OK (Gen.) Drlg. Rig: OK Flare Pit: N / A DIVERTER SYSTEM INSPECTION: Diverter Size: 20 in. Divert Valve(s) Full Opening: N / A Valve(s) Auto & Simultaneous: YES Vent Line(s) Size: 16" in. Vent Line(s) Length: 60 ft. Line(s) Bifurcated: NO Line(s) Down Wind: YES Line(s) Anchored: YES Turns Targeted / Long Radius: N/A TEST DATA ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: Not Witnessed Not Witnessed min. min. 6 @ 22OO MUD SYSTEM INSPECTION: Light Alarm Trip Tank: YES NW Mud Pits: YES NW Flow Monitor: YES NW GAS DETECTORS: Light Alarm Methane YES NW Hydrogen Sulfide: YES NW psig psig sec, sec, psig i!il !~. ; ': DIVERTER SCHEMATIC · Manifo, ld Bldg. ~ Production Flow Lines ~ ...................... ] PrevailingWinds 20" Annular Preventer With 16" FO Hydraulic Pad Access NORTH Pipe Shed & Motor Module Non Compliance Items 0 Repair Items Withi 0 Day (s) And contact the Inspector @ 659-3607 Remarks: I did not arrive on the North Slope until after the Diverter Function Test. I inspected for correct instalation. I traveled to the location and did an inspection of the entire system on 12/2/94. Distribution orig. - Well File c - Oper/Rep c - Database c - Trip Rpt File c- Inspector AOGCC REP.: OPERATOR REP.' BOBBY D. FOSTER BOBBY MORRISON FI-022 (Rev. 7/93 EBXIFICD.XLS Drtg Contractor: ., Operator: .. Well Name: Location: Sec. 1 STATE OF ALASKA ALASK/., _.iL AND GAS CONSERVATION COM[ Diverter Systems Inspe~lon Report SION Date: , 619195, Operation: Development X .... Exploratory: Parker Drilling Rig No, 24§ PTD # 95-8.2 Rig Ph. # Arco Ala,skB Oper. Rep,: .._., BOBBy MORRISON .._ 2T-26 Rig Rep.; ..... JOHN CRISP - DEARL GLADDEN T. _ 11 N R, 8 1= Merdien UM ..-~ , 767O MISC. INSPECTIONS; Location Gen,' OK Housekeeping: OKr (Gan.) Reserve Pit; N/A .. DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve{s) At,to & Simultaneous: Vent Line(s) Size: Vent Line(s) Length; Linels) Bifurcated: Line(s) Down Wind: Line(s) Anohored: Turns Targeted / Long Radius: ACCUMULATOR SYSTEM: Well Sign: OK Systems Pressure: 3000 psig Ddg, Rig: OK Pressure After Closure: 1700 psig Flare Pit: ' ' N/A 200 psi Attained After Closure: .... rain. 34~ sec, Systems Pressure Attained: ~2 mia, 45 se.(:, Nitrogen Bottles: 20 ir'~. Yes ,. Yes 16 .,, in, 90' fl. ' N/A Yes Yes 2100-2250-2250 · 2400-:2350-2300 MUD SYSTEM INSPECTION: Light Alarm Trip'Tank: N/_..._~_A NtA Mud Pits', O.___.L OK Flow Monitor; N/A N/A GAS DETECTORS: Light Alarm Methane OK OK Hydrogen Sulfide: O,K, '" ~)K psig Vent Line Non Compliance items Remarks: Distribution grig, - Well File c- Oatabaee = - Trip Rt'xt Fii~ ~ - Inspector FI.022 (Rev, 7t93 Repair Items Within "D~Y'(s) And con~'act the Inspector @ 659-3607 AOGCC REP.: OPERATOR REP,: CONTRACTOI~TR~,X,L$ ,.,WAIVED BY BOBBY FOSTER ._ BOBBY MOR, RISON CRISP. GLADDEN 9~ Parker 245 16" diverter line sketch Well ±20° 89.1' single 16" cliverter line Rig 21' 62.5' From well center t¢~ break flange = 3.5' From break flange to end (wheeled section) = 85.6' Note: Drawing not to scale dkp 6/14/§5 ALASKA OIL ~ GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVEI~NOI~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 22, 1995 Mike Zanghi, Drill Site Dev Supv ARCO Alaska lnc P O Box 100350 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 2T-26 ARCO Alaska Inc 95-82 478'FSL, 556'FWL, Sec 1, T11N, R8E, UM 1346'FSL, 1387'FWL, Sec 36, T12N, R8E, UM Dear Mr Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the Nodh Slope pager at 659-3607. jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALAb,,A OIL AND GAS CONSERVATION COMMISSk.~! PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill D lb Type of Well Exploratory D Stratigraphic Test [] Development Oil X Re-Entry E] Deepen [] Service [~ Development Gas r~ Single Zone X Multiple Zone [~] 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 81' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. ©. Box 100360, Anchorage, AK 99510-0360 ADL 25548, ALK 2662 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 478' FSL, 556' FWL, Sec. 1, TllN, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1092' FSL, 1357' FWL, Sec. 36, T12N, R8E, UM 2T-26 #U-630610 At total depth 9. Approximate spud date Amount 1346' FSL, 1387' FWL, Sec. 36, T12N, R8E, UM 6/8/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2T-27 9152' MD 1346 @ TD feet 15.0' ~ 120' MD feet 2560 6068' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 600' feet Maximum hole angle 56.78° Maximum~rface 1700 pslg At totaJ depth (TVD) 3 1 00 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Couplinc~ Length MD TVD MD TVD (include sta~le data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 12.25" 9.625" 40.0# L-80 BTC 3609' 41' 41' 3650' 2872' 770 Sx Arcticset III & HF-ERW 580 Sx Class G 8.5" 7" 26.0# L-80 BTC 9111' 41' 41' 91 52' 6068' 220SxClassG HF-ERW Top 500' above 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 Intermediate Production LinerdUN 0 ] 1995 Perforation depth: measured true vertical A,~tski~ 0ii & Gas Cons. Commission Anch0r;..'? 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report E] 20 AAC 25.050 requirements X 2~. I her%y certify that thj~ f~~is true and correct to the best of my knowledge, !" Signed i'~u~' Title Drill Site Develop. Supv. Date ::~'i~ Commission Use Only Permit Number I APl¥,u~ber IAppr°val date ? ~,,~'-~;~'2_, 50 /'O~ ,Z,O.~..~.-..,~' ~ ? ,~,.--~ Soecoverlotterfor - ~ '"" ~" other requirements Conditions of approval Samples required E] Yes 1~ No Mud logrequired [~] Yes J~ No Hydrogen sulfide measures .[~ Yes [~] No Directional survey required ,~ Yes [~ No Required workingpressureforBOPE ~] 2M /~ 3M ~ 5M ['~ 10M ['~ 15M Other:Original Signed By David W. Johnstonby order of / Approved by Commissioner the commission Date/,~ Form 10-401 Rev. 7-24-89 Submit in triolicate I . . , 10 11 12 13 14 15 16 17 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2T-26 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (3,650')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (9,152') according to directional plan. Run LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve and run cased hole cement bond logs. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly. Set and pressure test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RE6EIYED ~/~s~,a u~l & Gas Cons. Comrnissiort Anchors.;? DRILLING FLUID PROGRAM Well 2T-29 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.8 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and 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 and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1,700 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 2T-26 is 2T-27. As designed, the minimum distance between the two wells would be 15.0' @ 120' MD. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2T-26 surface/production casing annulus will be filled with diesel after setting 7" and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface. Risks in the 2T-26 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. The 7" casing will be topset above the Kuparuk and a 5" liner run to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.8 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. RECEIVED JUN 0 1 1995 Alaska 0il & Gas Cons. Commission Anchor~ ;r~ 400 _ O O c5 - 0 _ ~ 400 _ __ - ARCO ALASKA, Inc. Structure : Pad 2T Well : 26 Field : Kuparuk River Unit Location : North Slope, Alaska 800 _ 1200_ 1600_ 2000_ 2400_ 2800_ 3200_ 3600~ 4oooJ - 4400_ - 4800_ _ 5200_ _ 5600_ 6000_ I Created by : jones For: D P~-~SH IDote plotted : 24-May-95 Plot Reference is 26 Version #6. Coordinates are in fee[ reference slot #26. True Vertical Depths are reference RKB. TD LOCATION: 1346' FSL, 1587' FWL SEC. 56, T12N, R8E N 7.74 DEG E 5949' (TO TARGET) ***PLANE OF PROPOSAL*** TARGET LOCATION: 1092' FSL. 1.357' FWL SEC. 36, T12N, R8E RKB ELEVATION: 122' TARGET 'rvo=5764 TMD=8755 DEP=5949 NORTH 5895 ~T 801 KOP TVD=600 TMD=600 BEP=O 3.00 6.00BEGIN TURN TO TARGET TVD=B33 TMD=833 DER=9 8.54 .... East --> 400 0 400 800 1200 Begin Angle Drop K-5 _6400 _ _6000 _ 5600 5200 4800 4400 4000 _3600 - _3200 16.01 3 DEG / 100' DLS __2800 18.82 _ 0 21.69 24.58 B/ PERMAFROST TVD=1502 TMD=1531 DEP=185 '=~ 27.50T/ UGNU SNDS TVD=1547 TMD=1582 DEP=207 _2400 , 30.43 33.38 3~'g.~8 Estimoted Bose Tobosco -- 42.25 . K-10 _2000 45.22 4'8~.816 T/ W SAK SNDS WD=2192 TMD=2421 DEP=752 _ 54 13 9 5/8 Cos~ng Pt ~ 5 · EOC TVD=2293 TMD=2593 DER=872 ' 3/ W SAK_ S_ND_S ....... ~ RECEIVED Bose West Sok Sands ;1600 TVD=2672 TMD=3285 DEP=1451 9 5/8" CSG PT '"'%..".~ _ _ - _1200 ~'o--~o=36~o o~=17~ ~x% JUN 0 1 1995 K-lO ~0-=5063 TMD=5999 DER=2048 %,~ f - Est. B/ TABASCO ~ ~'"'"" Oil "- 0.. ~ ..... t~OC 800 P 0 /'~i¢..,..~',~, r,.x ~.1~ tau TVD--5143 TMD=4145 DEP=2170 ~ rl~.IJ0rrlmissi0rl lTop w~,t so~ so.d, - ...... - _ ~ Anch0ra;-n !opUgnu Sonds -400 MAXIMUM ANGLE ~-~ .o.~.... ,rost ] 1°1 56.?8 DEG ~ e/%;~ _o ~ ,o %, _ 400 LOCATION: 1 47~' FSL, 556' RNL ~ SEC. 1, T11N, R8E 56s°~'°°~°o~.Oo° D~O~2 D[~ / 100' S~.O0 ~t°oo .~.00 T/ ZONE A 'WD=5791 1MD=8790 DEP=5972~ m--T~,-'~'nm .-,,T,r~"r ~'m T/ A3 SNDS TVD=5808 TMD=8812 DEP=5986 XX~ I&t%LiJdJ'l AD4UL~ B/ KUP SNDS TVD=5915 TMD=8952 DEP=6076 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ , , , , , , , , ~ ~ ~ ~ ~ , , , , , , , , , , 400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 Scele 1 ' 200.00 Vertical Section on 7.74 azimuth with reference 0.00 N, 0.00 E from slot #26 I I ,.C iCreated by : jones For: D PETR~H JDate plotted : 24-May-95 J Plot Reference is 26 Version #6. I !Coordinates are in feet reference slot #26I True Vertical Depths are reference RKB. ' 80¸ ARCO ALASKA, Inc. Strucfure: Pad 2T Well : 26 Field : Kuparuk River Unit Location : North Slope, Alaska Scale 1' 10.00 East ~> 4-0 20 0 20 40 60 80 1 O0 120 140 160 180 200 220 240 260 280 I I II I I II I I I I I I I I I I I 1,7~0 1400 7O0 1500 1200 1400 1200 1600 1500 90O 1100 14oo 70O 600 lOOO 900 1200 30O 70 goo IlOO lOO 800 1100 1000 17oo 16oo _320 _300 _ _280 _ _260 _ _240 _ _220 _200 _ _180 _ _160 _ _140 120 0 ~ .4¢ ~*o.¢;® ~ ~ /~1500 // _ ~o o~ 330 - 4o I I I I I I I I I I I I I I I I 40 20 0 20 40 60 80 1 O0 120 14-0 160 180 200 220 240 260 280 ~co,~ ~. ~o.oo East Created by : jones For: D PE"]'RASH IDate plotted : 24-May-g5 Plot Reference is 26 Version #6. slot #26. Coordinates are in feet reference RKB. True Vertical Depths are reference Scale 1 ' 50.00 600 2800 _ 2700_ 2600_ 2500_ 2400_ 2300_ 2200_ 2100_ 2000_ -- 1900_ .-~ 1800_ I - 1700_ Z - 1600_ 15o0_ 1300_ _ 1200_ _ 1100_ _ 1000_ _ 900 ARCO ALASKA, Inc. Structure : Pad 21 Well : 26 Field : Kuparuk River Unit Location : North Slope, Alaska East --> 500 400 300 200 100 0 1 O0 200 300 400 500 600 700 800 900 1000 1100 I :°° 290 /490 4600 )C 2 3100 4400 4300 ~ 2600 3000 3100 3000 29OO 2800 2900 27OO 2600 25O0 2400 2500 3300 2400 I300 2200 2100 23OO 2600 3000 25O0 24OO 2900 2800 27OO 26O0 5700 36OO ;5OO ~400 4200 4100 4O00 3900 38OO ~500 2200 :400 500 3300 :7OO ~.700 320O i 600 500 400 .7K3,o 200 lOO o 1 aa 200 300 400 500 600 )oo East --> Scale 1 ' 50.00 JUN 0 1' 1995 ~800 _ _2700 _2600 _2500 _2400 _2500 _2200 _2100 _2000 1900 _1800 1700 600 1500 400 1300 2OO lO0 1000 9OO I 1100 Z 0 Alaska Oil & Gas Cons. Commission Anchorc I I .C Created by : jones For: D PETRASH Date plo[ted : 24-May-§5 Plot Reference is 26 Version #6. Coordinates ore in fee[ reference slot #26. True Vertical Dept~eference~ RKB. Scale 1 ' 20.00 1000_ _ 960 _ _ 920 _ 88O 84O _ 800 _ _ 760 _ _ 720 _ _ 680 640 600 _ _ 560 _ _ 520 _ _ 480 _ _ 440 _ 40O _ 360 _ -- 320 _ _ 280 _ 200 160 120 80 · I I I I I I I 2300 1900 2200 2100 1800 2000 40 21 O0 2000 1900 1900 1800 200 160 120 Scale I ' 20.00 4O 8O 1800 1700 1,500 1500 1500 1400 40 8O Easf 120 170( 16oo 120 160 20o0 19oo 180o 190o 1800 160 --> 2OO 2100 2800 2OO ARCO ALASKA, Inc. Structure ; Pad 2T Well : 26 Field : Kuparuk River Unit Location : North Slope, Alaska 240 280 320 360 400 440 I I I II I I I I I t200 2300 3100 3O00 I I I I 240 280 320 360 ~100 I I I I 400 440 _1000 _ 960 920 _ _ 880 _ _ 840 _ _ 800 _ _ 760 _ _ 720 680 _ 640 _ _ 600 _ _ 560 -- _ 520 _ _ 480 440 400 _ _ 360 _ _ 320 _ _ 280 /k I I 0 ~ JPARUK RIVER UNI'i 20" DIVERTER SCHEMATIC 4 5 3 2 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. , MAINTENANCE & OPERATION u PON IN ITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET, 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11~2/94 I ,6 , 1. I 13 5/8" 5000 PSISTACK ACCUMULATOR CAPACITY TEST CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURETO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'I'TOM PIPE RAMS. TEST BO'I-rOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BUND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRIllING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13--5/8"- 5000 PSI PIPE RAMS 5. 13-5/8"- 5000 PSI DRLG SPOOLW/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR WELL PERMIT CHECKLIST iE ,D , COMPANY PROGRAM: exp [] der ~ redrll [] aery [] oN,oFF ADMINISTRATION APPR DATE ENGINEERING 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary.. Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Y Operator only affected party .............. Y Operator has appropriate bond in force .......... Y Permit can be issued without conservation order .... Permit can be issued without administrative approval. . Can permit be approved before 15-day wait ....... APPR DATE 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved...~-~' 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~(F~(~ psig. 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y ~/ 31. Data presented on potential overpressure zones ..... ~/~ 32. Seismic analysis 9f shallow gas zones .......... ~ N 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . . ~. Y N [exploratory only] ~ GEOLOGY: ENGINEERING: COMMISSION: TAB C~mments/Instructions: HOW/jo - A:~FORMS%cheklist rev 03/94 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. * ALASKA COMPUTING CENTER * * ....... SCHLUMBERGER ....... * ~ * ............................ * COMPANY NAME : ARCO ALASKA INC. WELL NAME : 2T-26 FIELD NAME : KUPARUK BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 501032022300 REFERENCE NO : 95284 LIS Tape Verification Listing Schlumoerger Alaska Computing Center 4-SEP- 1995 12:40 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 95/09/ 4 ORIGIN : FLIC REEL NAME : 95284 CONTINUATION # : PREVIOUS REEL : · COMMENT : ARCO ALASKA INC, KUPARUK RIVER, 2T-26, API #50-103-20223-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 95/09/ 4 ORIGIN : FLIC TAPE NAME : 95284 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, KUPARUK RIVER, 2T-26, API #50-103-20223-00 TAPE HEADER KUPARUK MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD BIT RUN 1 95284 1ST STRING 2ND STRING 2T-26 501032022300 ARCO ALASKA INC. SCHLUMBERGER WELL SERVICES 4-SEP-95 BIT RUN 2 BIT RUN 3 1 11N 8E 478 556 122.00 122.00 80.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) o.ooo o.ooo PAGE: LIS Tape Verification Listing Schlumoerger Alaska Computing Center 4-SEP-1995 12:40 3RD STRING 8.500 7.000 9174.0 PRODUCTION STRING ' REMARKS: WELL DRILLED 9-JUNE-1995 TO 15-JUNE-1995. REAL-TIME MWD GAMMA RAY INTERVAL IS 3696' TO 9210' **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves~ all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 3687.5 9206.0 $ BASELINE CURVE FOR SHIFTS: GRCH.USIT CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH MWD 88888.0 88884.0 8987.0 8983.0 8978.0 8972.5 8950.0 8946.0 8941.0 8937.5 8926.0 8921.5 8911.0 8906.5 8892.0 8887.5 8869.5 8866.0 8859.0 8854.0 8843.0 8837.5 8835.0 8830.0 8824.0 8819.5 8~14.0 8809.0 8802.5 8797.5 8795.5 8791.0 8785.0 8780.0 8775.5 8770.0 8772.5 8767.0 LIS Tape Verification Listing Schlumberger Alaska Computing 8754.0 8748.0 8747.5 8742.5 8731.0 8725.5 8724.5 8718.5 8714.0 8708.5 8707.0 8702.5 8700.0 8695.0 8698.0 8691.5 8679.0 8672.5 8653.0 8645.5 8639.0 8631.5 8619.0 8611.0 8604.0 8595.0 8584.0 8577.0 8579.5 8572.5 8575.0 8567.5 8563.0 8556.5 8558.5 8551.0 8541.5 8533.5 8519.0 8510.5 8510.0 8502.0 8504.0 8497.0 8502.0 8495.0 8487.0 8481.0 8471.5 8465.0 8468.0 8462.5 8436.5 8429.5 8434.0 8426.5 8430.0 8422.0 8405.0 8398.5 8383.0 8376.0 8374.0 8366.5 8363.0 8355.5 8342.5 8336.0 8333.0 8326.0 8329.5 8323.0 8323.0 8316.0 8315.5 8308.5 8294.0 8287.0 8291.0 8283.0 8278.0 8271.0 8250.5 8242.5 8226.5 8218.5 8210.0 8202.0 8188.0 8180.0 8171.5 8164.5 8168.0 8159.5 8149.0 8142.0 8130.0 8121.5 8125.0 8119.0 ~105.0 8098.5 8100.5 8095.0 8081.0 8073.5 8078.0 8071.5 8069.0 8061.5 Center 4-SEP-1995 12:40 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-SEP-1995 12:40 PAGE: 8O45.O 8038.5 8041.5 8034.5 8007.0 7999.0 7986.0 7978.0 7981.0 7974.0 7969.0 7960.5 7960.5 7952.5 7950.0 7942.0 7935.0 7928.5 7892.5 7886.0 7880.5 7873.0 7864.0 7855.0 7859.0 7852.0 7844.5 7838.0 7832.0 7825.5 7826.0 7818.5 7811.0 7802.5 7806.0 7798.0 7789.5 7782.5 7773.5 7766.0 7762.5 7755.0 7750.0 7744.0 7740.0 7733.5 7717.5 7709.5 7706.0 7699.0 7689.0 7682.5 7678.0 7670.5 7654.0 7645.5 7642.0 7634.5 7624.0 7616.0 7618.5 7610.5 7609.0 7600.5 7592.0 7584.5 7578.5 7569.5 7562.5 7554.5 7556.0 7549.5 7554.5 7547.5 7549.5 7542.0 7540.0 7532.5 7529.0 7521.5 7510.0 7503.0 7489.0 7480.5 7475.5 7468.5 7440.0 7432.0 7420.0 7412.0 7405.5 7396.0 7401.0 7392.5 100.0 91.5 $ MERGE~ DATA SOURCE LDWG TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-SEP-1995 12:40 REMARKS: BASE GAMHA RAY USED FOR DEPTH CORRECTION WAS SCHLUMBERGER GRCH FROM THE USIT (ULTRA SONIC IMAGING TOOL) LOGGED 3-AUG-1995. THE GRCH.USIT CHANNEL WAS ONLY ACQUIRED FROM 8985' TO 7386', THE MWD DATA HAS A CONSTANT BLOCKSHIFT OF -8.5 FEET ABOVE THE GRCH.USIT LAST READING. $ LIS FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE i 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 -~~- ~,,~ ,wp ^A~ oo ooo oo o ~ ~ ~ 4 68 oooooooooo GRIN MWD AAPI O0 000 O0 0 1 1 1 4 68 0000000000 ~o~ ~ ~p,~ oo ooo oo o ~ ~ ~ ~ 68 oooooooooo GRCH USIT GAPI O0 000 O0 0 1 1 1 4 68 0000000000 ** D~TA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 9206.000 GRRW.MWD GRCH.USIT -999.250 DEPT. 3687.500 GRRW.MWD GRCH.USIT -999.250 ** END OF DATA ** 4-SEP-1995 12:40 -999.250 GRIN.MWD 60.902 GRIN.MWD -999.250 60.902 ROP.MWD ROP.MWD PAGE: 92.700 196.601 **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 3696.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: 'DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (Fl): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): STOP DEPTH 9210.0 15-JUN-95 REAL-TIME 9210.0 3696.0 9210.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-SEP-1995 12:40 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEC) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN~: . DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L~/~): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES [PPM): FLUID LOSS (~3}: . RESISTIVITY (OHMM} AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF EWR FREQUENCY 2.0 59.9 TOOL NUMBER 20.000 121.0 LSND/LCM REMARKS: DIRECTIONAL SURVEY SERVICE (DSS) WAS PICKED UP ON 9-JUN-95 AT 121' TO DRILL THE 12.25" HOLE TO 9.625" CASING POINT AT 3696'. DIRECTIONAL LOGGING SERVICE (DLS) WAS PICKED UP ON 11-JUN-95 TO DRILL THE 8.5" HOLE THROUGH THE TOBASCO SECTION TO 4438' WITH A MOTOR AND BUTTON BIT. DIRECTIONAL LOGGING SERVICE (DLS) WHICH INCLUDES THE MWD GAMMA RAY WAS RUN OVER THE ENTIRE 8.5" HOLE SECTION. $ LIS FORMAT DATA PAGE: LIS Tape Verification Listing Schlumoerger Alaska Computing Center 4-SEP-1995 12:40 PAGE: DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ..... ..... I 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 i ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP~-- PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 ..... i ..... ~ ..... ~ .... 6666666666- O0 000 O0 0 2 i 1 4 68 0000000000 GR RAW CPS GR MWD AAPI O0 000 O0 0 2 1 1 4 68 0000000000 GR INT AAPI O0 000 O0 0 2 1 1 4 68 0000000000 ROP MWD F/HR O0 000 O0 0 2 1 i 4 68 0000000000 ROP5 MWD F/HR O0 000 O0 0 2 I I 4 68 0000000000 ROP5 INT F/HR O0 000 O0 0 2 1 I 4 68 0000000000 VDEP MWD FT O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA DEPT. ROP.MWD DEPT. ROP.MWD 9210.000 GR.RAW -999.250 GR.MWD -999.250 GR. INT 92.000 ROP5.MWD 92.700 ROP5.INT 92.700 VDEP.MWD 3696.000 GR.RAW 16.000 GR.MWD 60.900 GR. INT 164.300 ROP5.MWD 196.600 ROP5.INT 196.600 VDEP.MWD -999.250 6089.900 60.900 2870.100 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 4-SEP-1995 12:40 PAGE: **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/09/ 4 ORIGIN : FLIC TAPE NAME : 95284 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, KUPARUK RIVER, 2T-26, API #50-103-20223-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/09/ 4 ORIGIN : FLIC REEL NAME : 95284 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, KUPARUK RIVER, 2T-26, API #50-103-20223-00
