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185-056
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3B-01 KUPARUK RIV UNIT 3B-01 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 3B-01 50-029-21318-00-00 185-056-0 W SPT 5954 1850560 3000 2842 2842 2842 2842 270 390 390 390 REQVAR P Bob Noble 6/7/2025 MIT-IA to max injection pressure as per AIO 2C.033 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 3B-01 Inspection Date: Tubing OA Packer Depth 660 3500 3330 3320IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250617135300 BBL Pumped:3.1 BBL Returned:2.8 Thursday, July 24, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3B-01 KUPARUK RIV UNIT 3B-01 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 3B-01 50-029-21318-00-00 185-056-0 W SPT 5954 1850560 3000 2898 2899 2899 2899 270 515 510 510 REQVAR P Austin McLeod 6/14/2023 Two year to MAIP. AIO 2C.033. 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 3B-01 Inspection Date: Tubing OA Packer Depth 580 3510 3340 3300IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230614192700 BBL Pumped:3 BBL Returned:3 Thursday, July 27, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9Two year to MAIP. James B. Regg Digitally signed by James B. Regg Date: 2023.07.31 11:00:05 -08'00' MEMORANDUM TO: Jim Regg �l 61t6 (�Z, P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 17, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3B-01 KUPARUK RIV UNIT 313-01 Src: Inspector Reviewed By: P.I. Suprv-�—E�2— Comm Well Name KUPARUK RIV UNIT 313-01 API Well Number 50-029-21318-00-00 Inspector Name: Lou Laubenstein Permit Number: 185-056-0 Inspection Date: 6/15/2021 Insp Num: mitL01-210616084527 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3B-01 - Type Inj `h' TVD 5954 ' Tubing 2590 2590 - 2590 , 2600 - PTDL 1850560 ' Type Test sPT'Test psi 3000 IA 1 550 3410 ,l 3250 _ 3230 BBL Pumped: 3 - 1BBL Returned: 3 - OA 300 s40 540 - 540 -- f Interval R-EQVAR P/F P _ Notes: MIT -IA to the Maximum Anticipated Injection pressure per AIO 2C.033. I— Thursday, June 17, 2021 Page 1 of 1 Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: / AOGCC ATTN: Natural Resources Technician If Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 1 •• TRANSMITTAL DATEi TRANSMITTALII Name Signature Please return via courier or sign/scan and email a copy Date and CPAI. Schlumberger -Private ATransmittal Receipt signature confirms that package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. rICE ORDER # FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE Color DATELOGGED Prints CD's 3B-01 50-029.21318-00 EOSH-00133 KUPARUK RIVER WL (PROF FINAL FIELD 10 -Jan -20 1 1H-111 1H-114 1H-119 11-1-115 IH -108B 1H-116 50-029-23581-00 50-029-23584-00 50-029.23591.00 50-029-23605-00 50-029.23608.02 50-029-23594-00 DWUJ•00160 DWUJ-00161 DWUJ-00162 DWUJ-00163 DWUJ-00164 DWUJ-00165 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL1 WL WL1 IPROF•WFL (PROF-WFL (PROF-WFL (PROF-WFL WFL (PROF FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 15 -Jan -20 16 -Jan -20 17-Jan10 18 -Jan -20 19 -Jan -20 20 -Jan -20 1 1 1 1 f 7 Name Signature Please return via courier or sign/scan and email a copy Date and CPAI. Schlumberger -Private ATransmittal Receipt signature confirms that package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. MEMORANDUM State of Alaska Alaska Oil and Cas Conservation Commission TO: Jim Regg /Q C l4 DATE: Monday, July 8, 2019 SUBJECT: P.I. Supervisor -y 4 t? Mechanical Integrity Tests ll ConocoPhillips Alaska, Inc. PTD I9505G0 Type Test s"I Test psi 313-01 FROM: Guy Cook KUPARUK RIV UNIT 313-01 Petroleum Inspector Src: Inspector Reviewed By: P.I. Sup" NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3B-01 Insp Num: mitGDC190628173316 Rel Insp Num: API Well Number 50-029-21318-00-00 Inspector Name: Guy Cook Permit Number: 185-056-0 Inspection Date: 6/282019 ' Packer Depth Pretest Initial IS Min 30 Min 45 Min 60 Min Well 3E-01 ' Typelnj w TVD 5954 Tubing 'o -c o-, 0-1 - 2072 PTD I9505G0 Type Test s"I Test psi 3000 IA 'S ,220 si,o 3110 BBL Pumped: 3 - BBL Returned: 3 OA 300 - 500 Ono 490 Interval REQVAR P/F i.._ _P.. ✓ __ Notes: MIT -IA every 2 years to maximum anticipated igjection pressure per AIO 2C.033. Job completed with a Little Red Services pump truck and calibrated analog gauges. ' Monday, July 8, 2019 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,June 16,2017 P.I.Supervisor / is(? ( 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3B-01 FROM: Matt Herrera KUPARUK RIV UNIT 3B-01 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Cie-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3B-01 API Well Number 50-029-21318-00-00 Inspector Name: Matt Herrera Permit Number: 185-056-0 Inspection Date: 6/7/2017 Insp Num: mitMFH170609141444 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3B-01 Type Inj W TVD 5954 - Tubing 2730 2730 2730 2730 - PTD 1850560 - Type Test SPT Test psi 3000 IA 1300 3420 3300 ' 3280 ' BBL Pumped: 2.7 " BBL Returned: 2,5 OA 325 515 - 505 - 505 - Interval REQVAR P/F P ✓ Notes: 3420 IA Test pressure per operator.AIO 2C.033 ✓ SCAN D AUG 1 5 2017 Friday,June 16,2017 Page 1 of 1 • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, March 07, 2016 11:00 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: Follow up of report of IA pressurization 3B-01 (PTD 185-056) Chris- The 30 day diagnostic gas injection monitor period for KRU WAG injector 3B-01 (PTD# 185-056) is coming to an end. The IA did not show any indications of TxIA communication. It is CPAI's intentions to return the well to normal WAG status. If at any point in time the well shows indications of communication,the well will be reported as needed. Please let me know if you have any questions or disagree with the plan. Attached is the 90 day TIO plot. Dusty Freeborn /Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907)943-0450 SCANNED APR 0 7 2012 1 410 Well Name 3B-01 Notes: Start Date 12/812015 Days 90 End Date 3/7/2016 Annular Communication Surveillance 4ECC - _L'JHP IAP OAP 4CCC — 4'JHT ?5Q01t � ��. - 12f 'CCC , r- 2ECC i 2CCC 1.CC1141 1CCC ECC — 2C c c 11o:-1E Geo-1E Jan-16 Feb-16 Mar-16 +pr-le -tet sac ,V„ a. GUM tl: �OCf tOt4 Noy-1E Deo-15 Jan-16 Feb-16 Mar-16 Apr-16 Date Chris, The 30 day diagnostic monitor period for KRU WAG injector 3B-01 (PTD# 185-056) is coming to an end. The IA showed pressure stabilization during the water injection period so the IA was put on an series of extended bleeds in an attempt to remove any gas from the system. After the IA bleeds were completed, the diagnostic MIT-IA and IA DDT passed. The tubing pack off tests both passed and the inner casing pack off tests passed in the negative direction. It is CPAI's intention to WAG the well to gas as soon as reasonably possible and monitor for 30 days. If the IA shows stabilization during the 30 day monitor period the well will be returned to normal status. If TxIA communication is confirmed while on gas injection the well will be WAG'd back to water injection and an application for continued water injection with TxIA while on gas will be submitted. Please let me know if you have any questions or disagree with the plan. 2 • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, February 01, 2016 7:41 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: RE: Report of IA pressurization 3B-01 (PTD 185-056) 31 Jan 16 Update Attachments: 3B-01 MIT-IA &IA DDT 31 Jan 16.xls Chris, The 30 day diagnostic monitor period for KRU WAG injector 3B-01 (PTD# 185-056) is coming to an end. The IA showed pressure stabilization during the water injection period so the IA was put on an series of extended bleeds in an attempt to remove any gas from the system. After the IA bleeds were completed,the diagnostic MIT-IA and IA DDT passed. The tubing pack off tests both passed and the inner casing pack off tests passed in the negative direction. It is CPAI's intention to WAG the well to gas as soon as reasonably possible and monitor for 30 days. If the IA shows stabilization during the 30 day monitor period the well will be returned to normal status. If TxIA communication is confirmed while on gas injection the well will be WAG'd back to water injection and an application for continued water injection with TxIA while on gas will be submitted. Please let me know if you have any questions or disagree with the plan. Attached is a current 90 Day TIO plot and a MIT-form containing the results from the diagnostic MIT-IA and IA DDT. Dusty Freeborn /Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 441WELLS TEAM Caxx bPlwilep SCONED JUL 2 5 2016 1 • Well Name 3B-01 Notes: Start Date 1112/2015 Days 90 End Date 113112016 Annular Communication Surveillance -Ecc - 4'JHP — 1 UIP OAP CCC — WHT – 1c °Scc – 12 2000 – 1C 2E0C — Sc Q 2CCQ riOr — 1`CC 1CCC ` - C `CC – 20 C C Oct-1E tic.-1E Ceo-1E Jan-1€ Fet-1L s000 d__ sox d34 IV‘1\0*/\°\1\i‘A, .. 1G7 Oct-1F Mc -1F Dec-1S Jan-16 Feb-16 Date From: NS roblem Well Supv Sent: Wednes a , December 30, 2015 5:01 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of IA pressurization 3 - PTD 185-056) 12-30-15 Chris, Kuparuk WAG injector 3B-01 (PTD 185-056) is displaying an unexplained i surization while on gas injection. CPAI plans to WAG the well to water injection as soon as possible and monitor for 30 da . ecause of the current slow build in pressure and historic test results on other wells displaying similar characteristics, we do not-expect the well to fail the 2 • S Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, December 30, 2015 5:01 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of IA pressurization 3B-01 (PTD 185-056) 12-30-15 Attachments: 3B-01 schematic.pdf Chris, Kuparuk WAG injector 3B-01 (PTD 185-056) is displaying an unexplained IA pressurization while on gas injection. CPAI plans to WAG the well to water injection as soon as possible and monitor for 30 days. Because of the current slow build in pressure and historic test results on other wells displaying similar characteristics, we do not expect the well to fail the MIT. Therefore we plan to delay the MIT and other initial DHD tests which will include packoff testing and an extended IA pressure bleed (possible to take several days)till towards the end of the 30 day monitor on water. Following the 30 day diagnostic test period on water,a request may be submitted for another test on gas injection or an AA application for continued water only injection will be submitted. Please let me know if you disagree with this plan. Attached are the 90 day TIO plot and schematic. SCAN ED SEP 1 9 2016 1 Well Name 3B-01 Notes: Start Date 10(1/2015 Days 90 End Date 12(3012015 Annular Communication Surveillance 45cc - _WHP - 1- LAP OAP 46U0 — b'c/HT — 12 2E00 77"1.1 ; — 10 ?Cc0 2500 — gC .47 2C00 — £C 1E00 - e.c 1C00 — 20 `c0 0 c Sep-1S Qct-1 E td c•;-1E Dec-1E Jan-1 acao -� Ada ▪ :SCA: :Nt m▪ it 'LPG LL �1- Sep-1E Oct-15 N au15 Dec-15 Jan-16 Date Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr 909 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,June 24,2015 TO: P.I.JRSupervisor � C12( �1 SUBJECT: Mechanical Integrity Tests P.I.Su ervisor I CONOCOPHILLIPS ALASKA INC 3B-01 FROM: Chuck Scheve KUPARUK RIV UNIT 3B-01 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3B-01 API Well Number 50-029-21318-00-00 Inspector Name: Chuck Scheve Permit Number: 185-056-0 Inspection Date: 6/18/2015 Insp Num: mitCS150621101631 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Weill --- 3B-01 Type Inj W iTVD 5954 Tubingi 2815 2815 - 2817 - 2817 - PTD 1850560 Type Test SPT Test psi 1500 - IA 1010 2000 • 1960 1950 . Interval 4YRTST P/F P '" OA 300 380 - 380 380 Notes: SCANNED ` ` r Wednesday,June 24,2015 Page 1 of 1 (175-651, WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 27, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 cJa RE: Injection Profile: 3B-01 Run Date: 12/18/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3B-01 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21318-00 Injection Profile Log 1 Color Log 50-029-21318-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: Signed: 6aeede(I Ima ect Well History File' ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. -~ F~-' (~)'~' ~- Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes. No. [] Maps: [] Grayscale items: [] Other. No/Type [] Other items scannable by large scanner [3 Poor Quality Originals: ~, OVERSIZED (Non-Scannable) [] Other: , NOTES: [] Logs of various kinds [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: /S/ Scanning Preparation '/~ x 30 = + = TOTAL PAGES Production Scanning Stage 1 PAGE COUNT FROM SCANNED F,LE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES ~NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~S NO (SCANN~G ~ COMPETE AT ~IS ~ UN~ ~EC~ A~ENTION IS RE~IRED ~ ~ ~O~UAL PAGE BAS~ ReScanned (individual page [special attention] scanning completed) RESCANNEDBY.' BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd • • Nov . Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 30, 2011 ` j 05 Co Commissioner Dan Seamount ! a' Alaska Oil and Gas Commission Q1: 333 West 7 Avenue, Suite 100 r ti V G('. �trt t,i$Sio►i Anchorage, AK 99501 :,0crH6 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 5/23, 2011. The corrosion inhibitor /sealant was pumped 6/22, 6/24, 6/25, 6/26, and 6/27, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, MJ Lo land ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) 1 Kuparuk Field Date 6130111 2F,2M,2N,2T,2X,2Z,3B,30 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 2F -19 50029227280000 1962010 8" N/A 23" N/A 13 6/25/2011 2M -09A 50103201770100 1960900 ' SF N/A 18" N/A 3.5 6/26/2011 2M -14 , 50103201730000 1920630 SF N/A 19" N/A 3.5 ' 6/26/2011 2M -17 50103201500000 1910180 SF N/A 19" N/A 3.5 6/26/2011 2M -26 50103201720000 1920550 SF N/A 21" N/A 3.5 6/26/2011 2N -316 50103203420000 2000900 _ SF N/A 18" N/A 4 6/27/2011 2N -318A 50103203430100 2090220 10" N/A 27" N/A 7 6/27/2011 2T-40 50103205280000 2060400 2' N/A 2' N/A 6 6/26/2011 2T -202 50103202540000 1980370 6" N/A 20" N/A 9 6/26/2011 2X -07 50029209910000 1831130 SF N/A 21" N/A 2 6/25/2011 2X -08 50029209920000 ' 1831140 ' SF N/A 21" N/A 2.5 6/25/2011 2Z -02 50029209600000 1830800 18" N/A 18" N/A 2.6 6/24/2011 38 50029213180000 ' 1850560 SF 1.50 17 5/23/2011 6 6/22/2011 30 -12 50029218040000 _ 1880410 SF N/A 22" N/A _ 1.7 6/22/2011 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission i // DATE: Wednesday, June 22, 2011 TO: Jim Regg lk /i ? W P.I. Supervisor / SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3B -01 FROM: Bob Noble KUPARUK RIV UNIT 3B -01 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry . j S'ee- NON CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3B - 01 API Well Number: 50 029 - 21318 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110621150533 Permit Number: 185 - 056 - Inspection Date: 6/19/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well r 313-01 ` Type Inj. G , TVD 1 5954 ' IA I 1700 2292 • 2266 2257 - P. T.D 1850560 ' TypeTest _ SPT Test psi _ 2292 • OA 360 390 390 390 Interval 4YRTST p/p' P . Tubing 3358 3358 , 3356 3356 Notes: .7 bbls to pressure the IA up. .:: '' JUN 2, 4 2O1 Wednesday, June 22, 2011 Page 1 of I • • s [E ciT ziaAsEn SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 CANCELLATION ADMINISTRATIVE APPROVAL AIO 28.021 Ms. M. J. Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. JUN Z P.O. Box 100360 Anchorage, AK 99510 -0360 RE: Cancellation of Administrative Approval AIO 2B.021 KRU 3B -01 (PTD 1850560) Kuparuk River Oil Pool Dear Ms. Loveland: Pursuant to ConocoPhillips Alaska, Inc. (CPAI)'s request dated September 26, 2010 the Alaska Oil and Gas Conservation Commission (AOGCC) hereby cancels Administrative Approval AIO 2B.021, which allows continued water injection in Kuparuk River Unit (KRU) well 3B -01. This well exhibited a shallow surface casing leak to atmosphere and CPAI did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. CPAI has since performed a welded repair to 3B -01. An MITOA was successfully conducted following repair. Consequently, Administrative Approval AIO 2B.021 no longer applies to operation of this well. Instead, injection into KRU 3B -01 will be governed by provision of the underlying AIO No. 2B. DONE at Anchorage, Alaska and dated October 1, 2010. / X rpi Daniel T. Seam. unt. Jr. Cathy :. Foerster y r�:. e•�,. Commissioner, Chair Commissioner • • AIO 2B.021 cancel October 1, 2010 Page2of2 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may tile with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration. this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided m AS 31,05,080(b), °It]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period, the last day of the period is included, unless it falls on a weekend or state holiday. in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 3B-O1 Run Date: 7/21/2010 August 11, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3B-O1 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21318-00 ~[ +7~a~~r5 14`I ~~ i f1 ~~)Ff i,_I6 y,, ` ~. A, ..bA~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating tJZ.C Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood Date: a ,~ ~+ /~J~_~'~ a~ Signed: • ~ ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, November 23, 2009 8:34 AM To: 'NSK Welt Integrity Proj'; Schwartz, Guy L(DOA); Regg, James B(DOA) Cc: NSK Prablem Weli Supv Subject: R. 3B-01 (PTD 185-056, AIO 26 21) Page 1 of 1 MJ, I support your p(an to keep the AA in place. Although the platelet application appears to have worRed, it makes sense to continue monitoring until the "hard fix" is welded in place. Tom Maunder, PE AOGCC _ __ _ From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Sunday, November 22, 2009 6:01 PM To: Maunder, T'homas E(DOA); Schwartz, Guy L(DOA); Regg, 7ames B(DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj SubjeCt: 3B-01 (PTD 185-056, AIO 28 21) Tom, Injection well 3B-01 (PTD 185-056, at0 26 21), recently had the surface casing leak repaired with Brinker Platetets and passed a 1000 psi MITOA. Even though the repair was suceessfut, ConocoPhiUips intends to cantinue to operate the well under AIO 2B 21 until the welded surface casing patch is completed in the near future - currently scheduled for first quarter. Our reasons for this are there is no gas available on the pad so no oil benefit of removing the AA and having it in place gives the well a little more atten#ion than a normal well. The AA will be canceled after the welded repair is completed. Please let me know if there are any issue with plan. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. O#Fce (907) 659-7043 Cell (907) 943-1687 ~`~~~~~~ ~~` C i~ ~ ~ 2C~~ 11/23/2009 • • RECEIVED N0V 1 7 2krf:, ConocoPhillips Alaska Alaska Qli &Gas Cons. Commission P.O. BOX 100360 Anchorage ANCHORAGE, ALASKA 99510 -0360 November 14, 2009 Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission 333 West 7 th Avenue, Suite 100 Anchorage, AK 99501 S&ANKD 5 ~ C 1 8 2009 I Dear Mr. Schwartz: Enclosed please find the 10 -404 Report of Sundry well operations for ConocoPhillips Alaska, Inc. well 3B -01, PTD 185 -056 surface casing repair with Brinker Platelets. Please call Perry Klein or me at 659 -7043 if you have any questions. Sincerely, M Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures EGE1Vt- • • NOV I r1 2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. COt111'nISSIAn REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon ❑ Repair Well E Plug Perforations ❑ Stimulate ❑ Other O Repair Sc w Platel Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program O erat. Shutdown Perforate ❑ 9 PP 9 ❑ P ❑ ❑ Re -enter Suspended Well 2. Operator Name: 4. Current Well Status: Permit to Drill Number: COnocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 185 -056 3. Address: Stratigraphic ❑ Service ❑ API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21318 -00 KB Elevation (ft): Well Name and Number: RKB 85' 3B -01 Property Designation: 10. Field /Pool(s): ADL 25633, ALK 2566 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured X7690' feet true vertical 6405' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SURF. CASING 3272' 9 -5/8" 3357' 3252' 3520' 2020 PROD. CASING 7592' 7" 7677' 6396' 4980' 5250 Perforation depth: Measured depth: 7166 -7258, 7280 -7288, 7403 -7430, 7451 -7490 true vertical depth: 6018 -6085, 6101 -6107, 6191 -6211, 6228 -6256 Tubing (size, grade, and measured depth) 3.57 2 -7/8 ", J -55, 7326 / 7342 MD. Packers & SSSV (type & measured depth) pkr= OTIS 'RH' ; OTIS 'WD' pkr= 7079'; 7317' SSSV= SSSV SSSV= 1902' 12. Stimulation or cement squeeze summary: NA Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casina Pressure I Tubinq Pressure Prior to well operation NC Subsequent to operation I NC 14. Attachments Ilk Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ❑ Development ❑ Service ❑ Daily Report of Well Operations _X 'V. Well Status after proposed Oil❑ Gas❑ WAG GINJ❑ WINJ [ _ WDSPL❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Num or N/A if C.O. Exempt: 309 -306 Contact MJ Loveland /Per Klien Printed Name MJ Loveland Title WI Proj Supervisor Signature Phone: 659 -7043 Date ; d RWMINNOV 18 2009 Form 10 -464 Revised 04/2004 Submit Original Only • 3B -01 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/25/09 SC Leak Repair - Successful (Brinker Platelet), Initial T /1 /0= 2800/910/0. Shot OA FL @ 35' (600 fps). FL in the conductor was unknown. Rigged up triplex to injection manifold and - established several LLR with diesel 3 gallons of diesel @ 80 psi for 27 seconds; 3 gallons of diesel @ 80 psi for 29 seconds; 3 gallons of diesel @ 80 psi for 26 seconds. Swapped over to diesel gel and performed same LLR, 3 gallons of diesel gel @ 100 psi for 34 seconds, 3 gallons of diesel gel @ 100 psi for 31 seconds. Start to infect platelets, 10 -12mm spheres qmmped r 5 minutes until OA reached 1000 psi. held for 5 min. Attempted to pressured up OA higher but could only reach 1060 psi. Pumped continuously for 3 minutes with no change. Start MITOA @ 1060 psi, T /1 /0= 2800/950/1060, 15 min T /1 /0= 2800/950/1060, 30 min T /1 /0= 2800/950/1065, 45 min T /1 /0= 2800/950/1060, 60 min T /1 /0= 2800/950/1060. Bleed OA down to 500 psi. Pumped approximately 3 bbls of gel diesel. Shot IA FL @ 2050'(600 fps). Stung into IC PO TP with 290 psi, Bled to 0 psi with 0+ build up in 15 min. Final T /1 /0= 2800/925/500. 10/27/09 Called and invited State inspector to witness MITOA tomorrow - no call back 10/28/09 MITOA - Passed. Initial T /1 /0= 2820/900/550. OA FL AS. Pressured up OA to 1000 psi with 1/4 bbl of diesel gel. Start MITOA, T /l /0 = 2820/900/1000, 15 min T /l /0 = 2820/900/985, 30 min T /I /0 = 2820/900/985. Bleed OA down to 340. Final T /I /0 = 2820/900/340. Summary Repaired SC leak with Brinker Platelets ■ r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks @alaska.gov; tom.maunder@alaska.gov; doa .aogcc.prudhoe.bay @alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 313-01 DATE: 10/27/09 OPERATOR REP: Phillips / Westlake AOGCC REP: State rep was notified with no response Shoe Depth Pretest Initial 15 Min. 30 Min. Well 313-01 I Type Inj. I W TVD 1 3,252' Tubing 2,8201 2,8201 2,8201 2,8201 Interval O P.T.D. 11850560 1 Type test I P I Test psi 1000 Casing 900 900 9001 900 P/F P Notes: 0A 5501 10001 9851 985 MITOA Test per Sundry 309 -306 - Entered Shoe TVD in Packer slot. Weill I Type Inj. I I TVD I Tubing Interval P.T.D.1 I Type test I I Test psi I Casing P/F Notes: OA Well Type Inj. N TVD Tubing Interval P.T.D. Type test P Test psi Casin P/F Notes: OA Weill I Type In'. TVEps Tubing Interval P.T.D. Type test Tes Casing I I P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. I Type testl I Test psi I asing P/F Notes: I OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 36 -01 10- 27- 09.)ds ~ ~`= ~~d. ~~~~'''- °~ ~ ~ ~y' ggg g ~ ~ F ~ F S~ R ~` ~~ ~ ~ ~ ~ ~ ~ ~ ~~~ ~ ~ ~ p4 ~ ~~ P~ ^ ~..a ~ ~~ ~Y ~ ~: q ~ ~~ ~ ~~~ ~ ~ ~~' ' ~~ ' ~; ~ ~ ~, ~ A~-,'' ~ ~ ~ .~ ~ „~; ~ `~' ~~ ~ ~ ~~.~~ ~ ~ ~~~ a ~~ ~ ~~ ~~~~ ~~ - ~,~ ~ ~ ~s~ ou ~n c~s ~~ CO1~T5ERQATIOK CO1~Il~IISSIOI~T ~ Mr. M.J. Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. ,. ; ,; ~;,~~ ; ~ ~~ :; P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 3B-O1 Sundry Number: 309-306 Dear Mr. Loveland: • SEAN PARNELL, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~5' ~ ~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Cha.ir DATED this ~da of Se tember 2009 - y P , Encl. • • ~ • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 28, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~.l w=`~ ~,~ 'R:' k ~ .. ~ ... . .. •, '~. .::..... .... ; ,. - x ;. a ~ ~ i ~ ~~ ~; ~.. _.~ ~~,_ ,~. Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 3B-O1 (PTD 185-056) surface casing repair. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, ~~~~ ~~~. J Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures " ~ ~ »:~: / • ° ~ . ~,Mi ~ STATE OF ALASKA ~; E ~_ ~; ~ ~!" ~'";;; % L / ~ q ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~ ~ ~j'~APPLICATION FOR SUNDRY APPROVAL~~~ ~~ ~~ ~ ~~ ~~~ " °~ -~~'~~4 ~`"~'"`' ~ ~ a 2~ AAC 25.28~ _ 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other _~/ Alter casing ^ Repair well /^ Plug Pertorations ^ Stimulate ^ Time Extension ~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ platelet Patch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ~eve~opment ~ Exploratory ^ 185-056 . 3. Address: Stratigraphic ~ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21318-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y@S NO Q 36-01 • 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25633,' ALK 2566 RKB 85' • Kuparuk River Field / Kuparuk Oil Pool • 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth Mo (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 7690' • 6405' ' Casing Length Size MD ND Burst Collapse CONDUCTOR 110' 16" 110' 110' SURF. CASING 3272' 9-5/8" 3357' 3252' 3520 2020 PROD. CASING 7592' 7" 7g77' 6396' 4980 5250 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7166-7258, ~2so-72ea, 7403-7430, 7451-7490 6018-6085, 6101-6107, 6191-6211, 6228-6256 3.5~Y 2-7/8" J-55 7326 / 7342 Packers and SSSV Type: Packers and SSSV MD (ft) pkr- OTIS'RH' ; OTIS 'WD' pkr- 7079' ; 7317' SSSV= SSSV SSSV= 1902' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service ~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: ` October 15, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ~^ ~ WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and rect to the best of my knowledge. Contact: MJ Loveland/Perry Klien Printed Name MJ Lovela d Title: WI Proj Supervisor - Signature ~'~ Phone:659-7043 Date ~ ~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Q~ ~p Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: ` / b -`/o l ,~~ ~ ~~ '~ -~ i APPROVED BY ~ ~ ~ ~ ~ Approved by: ~ COMMISSIONER THE COMMISSION Date: Form 10-403~Re~sed 06/2006 ~ ~i~R-~~ ~~ ;~ r` ~~ 113~~~ Su mit in Duplica e ~%~y ~~~~ ~ z~~9 ~ • q ~ ? 1 ~..~.a Y,.r.'~{ ConocoPhillips Alaska, Inc. Kuparuk We113B-Ol (PTD 185-056) SUNDRY NOTICE 10-403 APPROVAL REQUEST August 28, 2009 ff _~ ..... k~.~' ~. i u :._ This application for Sundry approval for Kuparuk we113B-O1 is for the repair of a surface casing leak. The injection well, drilled and completed in 1995, was previously reported as having a surface casing leak near surface. It currently is operating under AA AOI 2B-021. Subsequent testing indicated the leak depth in the surface casing approximately 4' down from the OA valve. For technology development and due to the back log of surface casing excavation repairs ConocoPhillips is planning a temporary repair with Brinker Platelets (long term plans still • include a conventional welded patch, approved Sundry 307-359). Platelets are free floating (neutral density) discrete particles which are injected into the system (in this case the OA) and transported with the fluid flow and entrained in the leak with fluid force thus providing a seal. The Platelet material is entirely inert, designed to function in oil and gas applications, and within the operating conditions of the well. Each particle is individually sized to fit the predicted leak geometry. With approval, repair of the surface casing will require the following general steps: 1. Rig up Platelet manifold to OA 2. Establish liquid leak rate; 3. Deploy a finite number of Platelets; 4. Maintain specified pressure on OA for a specific amount of time (to be determined by Platelet Tech, however probably less than 1000 psi). 5. MITOA to 1800 psi; 6. Return well to normal operations, however maintaining some positive pressure on OA. 7. File 10-404 8. Excavate and repair surface casing (Sundry 307-359) as schedule allows. ~ MEMORANDUM To: Jim Regg ~~~ 7~2 z,'(~ ~ P.I. Supervisor FRONt: Chuck Scheve Petroleum Inspector r1 LJ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integriry Tests CONOCOPHILLIPS ALASKA INC 3B-O 1 KUPARUK RIV UNIT 3B-Ol Srr. Inspector Reviewed By: P.I. Suprv ~ NON-CONFIDENTIAL Comm Well Name: KUPARUK RN iINIT 3B-O1 Insp Num: mitCS090608141327 Rel Insp Num: API Well Number: 50-029-21318-00-00 Permit Number: 185-056-0 ~' Inspector Name: Chuck Scheve Inspection Date: 6/7/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ 3B-O1 Type Inj. W T~ 5954 ° jA 1260 3000 '~ 2910 2870 2860 P.T.D 1850560 TypeTest SPT Test psi isoo / QA 4 7 7 7 7 Interval ~QVAR p~F P ~ Tubing 2690 2690 2690 2690 2690 Notes• MITIA required by AIO 2B.021 / _ ~ r r~ t~~~ii: i ka2 !'~~ i°' i ''~ ' ~ .. J , , Wednesday, June 10, 2009 Page 1 of 1 ~, ~. ~ k~ k~ z~ ~Q ~~ CO1~T5ER~TIO C01- IISSICO MJ Loveland • SARAH PAL/N, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 WI Project Supervisor Conoco Phillips Alaska, Inc. PO Box 100360 ~"~'~~1~E~ DEC 1 ~ 2047 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3B-O1 ~`~' ~5 Sundry Number: 307-359 (~ ~ ~~ Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this .~ day of December, 2007 Encl. Sincerely, • ConocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 24, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 • ~0~ ~ 7 2007 Alaska Di1 ~ Gay Cone. C~mmissiQr, Anchorage Dear Mr. Maunder: Enclosed please find a 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. we113B-O1 (PTD 185-056) to excavate and inspect and repair the casing for corrosion damage. Please call me or Perry Klein at 659-7043 if you have any questions. Sincerely, ,,: ~f~ M oveland Well Integrity Project Supervisor Attachments ~ Irv STATE OF ALASKA ~~ ltd ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~ ~. ~ad7 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Oii & Gas Cons. Commissitln 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ WaiveAncM®age Other ^ Alter casing ^ Repair well ^~ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 185-056 '" 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21318-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO Q 3B-01 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25633, ALK 2566 ' RKB 85' ~ Kuparuk River Field / Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7690' ~ 6405' . Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 16" 110' 110' SURF. CASING 3272' 9-5/8" 3357' 3252' 3520 2020 PROD. CASING 7592' 7" 7677' 6396' 4980 5250 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7166-7258, 7280-7288, 7403-7430, 7451-7490 6018-6085, 6101-61 07, 6191-6211, 6228-6256 3.5"~ 2-7/8" J-55 7326 / 7342 Packers and SSSV Type: Packers and SSSV MD (ft) pkr= OTIS 'RH' ; OTIS 'WD' pkr= 7079' ; 7317' SSSV= SSSV SSSV= 1902' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q " 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: April 1, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/ferry Klien Printed Name MJ Loveland Title: WI Proj Supervisor Signature Phone: 659-7043 Date ~~ Commission Use Onl Conditions of a roval: Notif Commission so that a re resentative ma witness Sun®)~ber: pp y p y Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Can~GC..~ S'~S~rcCr~ C-' °~j ~ ~~~~~ ~~ ~~~.~ SC's `LC9,~~ iC~ ~ ~ ~~C7.\~.. Subsequent Form Required: W ~ ~ ~~~~~ ~ ~ ~DD1 P R E Approved by: ~ OMMISSIONER I I N Date: ~ ~' ~Q Form 10-403 Revised 0612006 Submit in Duplicate - • • ConocoPhillips Alaska, Inc. Kuparuk We113B-Ol (PTD 185-056) SUNDRY NOTICE 10-403 APPROVAL REQUEST November 24, 2007 s This application for Sundry approval for Kuparuk we113B-O1 is for inspection and repair of the surface casing due to corrosion. The well an injection well, drilled and completed in 1995. It was previously reported as having a surface casing leak near surface. It currently is operating under AA AOI 2B-021. This request is for approval to excavate, and repair the leak. With approval, inspection and repair of the surface casing will require the following general steps: Safe-out the well with plugs and load the tubing and IA with seawater and diesel freeze protection cap. 2. Excavate wellhead location. 3. Install nitrogen purge equipment. 4. Cut away the conductor casing and remove cement around surface casing leak for inspection. 5. Notify AOGCC Field Inspector of repair operation so they may witness the event. '~ 6. Repair damaged surface casing to return the casing to operational integrity. Repair options include sleeve patch, seal weld, lap patch, deposition weld and will be determined after inspection of the casing damage. 7. QA/QC the repair welds and MIT-OA to verify integrity. 8. Install anti-corrosion coating on exposed surface casing. 9. Replace the conductor and top off void with cement and waterproof sealant. 10. Backfill gravel around the wellhead. 11. Remove plugs and return the well to production. 12. Submit 10-404 report of repair operations to AOGCC. AIO 2B-021 would also be canceled after a successful repair. • ID s AltuKn v SARAH PAULA, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3639 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL 2B.021 Mr. Brent Rogers Problem Well Supervisor ConocoPhillips Alaska, Inc. Y,7 JUN kl 6 Z Q'Il P.O. Box 100360 Anchorage, AK 99510 -0360 RE: KRU 3B -01 (PTD 1850560) Request for Administrative Approval Dear Mr. Rogers: In accordance with Rule 9 of Area Injection Order ( "AIO ") 028.000, the Alaska Oil and Gas Conservation Commission ( "AOGCC" or "Commission ") hereby grants ConocoPhillips Alaska Inc. ( "CPAI ")'s request for administrative approval to continue water injection in the subject well. Kuparuk River Unit ( "KRU ") 3B -01 exhibits communication between the surface casing and conductor at approximately 50 inches below the annulus valve. Mechanical integrity tests performed on the well's inner annulus ( "IA ") demonstrate the well has competent tubing and production casing. The Commission finds that CPAI does not intend to perform repairs at this time, but does intend to patch the surface casing within 24 months. The Commission further finds, based upon reported results of CPAI's diagnostic procedures and wellhead pressure trend plots, that KRU 3B -01 exhibits at least two competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection in KRU 3B -01 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall perform an MIT -IA every 2 years to 1.2 times the maximum anticipated injection pressure; 4. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; A1O 2B.021 • • November 1, 2007 Page 2 of 2 5. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection, and 6. The MIT anniversary date is June 8, 2007. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DONE at Anchorage, . ska and dated November 5, 2007. dir '01.11. P e t an Daniel T. Seamount, Jr. Chas • Commissioner j ' .-� s ✓ Ns , ' 1 x ,!. ‘I r . • • ConocoPhillips Alaska P.O. BOX 100360 44 # . " ANCHORAGE, ALASKA 99510-0360 A � chO' g ss ' oo October 20, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ConocoPhillips Alaska, Inc. presents the attached proposals as per AIO 2B, Rule 9, to apply for Administrative Approval to allow well 3B-01 (PTD 185 -056) to be online in water only injection service with known OAxOOA communication. ConocoPhillips intends to pursue a welded sleeve repair option for the surface casing leak. Repair is expected within the next 24 months. Application for the appropriate 10- 403 sundry will be made before initiation of repair. If a successful repair is achieved we will request the well be returned to normal status and resume the ability for MI injection. If you need additional information, please contact either myself or MJ Loveland at 659- 7043, or Brent Rogers / Martin Walters at 659 -7224. Sincerely, (7 (12 Arr K1 Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Attachments • • 144 Conoco Phillips Alaska, Inc. KRU 3B -01 3B -01 API: 500292131800 Well Type: INJ Angle C, TS: 43 deg a 7163 SSSV SSSV Type: Locked Out Oriq Completion: 4/14/1985 Angle A TD: 42 deg an, 7690 302 -1903, Annular Fluid: Last W /O: Rev Reason: Taq fill Reference Loq: Ref Loq Date: Last Update: 1/14/2004 Last Tag: 7567 ELM TD: 7690 ftKB Last Tag Date: 11/24/2003 Max Hole Angle: 45 deq a 6200 Casing String - ALL STRINGS Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 H-40 SURF. CASING 9.625 0 3357 3252 36.00 J -55 I PROD. CASING 1 7.000 1 0 1 7677 1 6396 26.00 1 J -55 1 Tubing String - TUBING 111 will Size Top Bottom TVD Wt Grade Thread 3.500 0 7326 6135 9.30 J -55 8RD EUE 2.875 7326 7342 6146 6.50 J -55 8RD EUE ■■� Perforations Summary �!'�� Interval TVD Zone Status Ft SPF Date Type Comment 7166 - 7258 6018 - 6085 ;-3,C- 2,C -1,l 92 12 6/3/1985 IPERF 5" Scalloped Gun, 120 deg B ph JIB ION 7280 - 7288 6101 - 6107 UNIT B 8 12 6/3/1985 IPERF 5" Scalloped Gun, 120 deg ph 7403 - 7430 6191 - 6211 A -3 27 4 6/3/1985 IPERF 4" Carrier Gun, 120 deg ph It EOM 7452 - 7490 6228 - 6256 A -2 38 4 6/3/1985 IPERF 4" Carrier Gun, 120 deg ph Gas Lift MandrelsNalves St MD TVD 1 Man Man Type V Mfr 1 V Type 1 V OD 1 Latch 1 Port 1 TRO 1 Date 1 Vlv 11 Mfr Run Cmnt 1 1955 1955 Merla TMPD DMY 1.0 BK 0.000 0 6/5/1985 2 3132 3069 Merla TMPD DMY 1.0 BK 0.000 0 6/5/1985 3 4072 3777 Merla TMPD DMY 1.0 BK 0.000 0 6/5/1985 4 4519 4099 Merla TMPD DMY 1.0 BK _ 0.000 0 6/5/1985 5 4965 4426 Merla TMPD DMY 1.0 BK 0.000 0 6/5/1985 6 5472 4795 Merla TMPD DMY 1.0 BK 0.000 0 6/5/1985 11 7 5917 5115 Merle TMPD DMY 1.0 BK 0.000 0 6/5/1985 8 6419 5472 Merla TMPD DMY 1.0 BK 0.000 0 6/5/1985 9 6923 5840 Merle TMPD DMY 1.0 BK 0.000 0 6/5/1985 , 10 7023 5913 Merla TPDX DMY 1.5 RA 0.000 0 6/5/1985 i f Injection Mandrels /Valves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 11 7117 5982 Merle TMPD DMY 1.0 BK 0.000 0 9/1/1996 Other (plugs, equip., etc.) - JEWELRY Depth TVD Type Description ID 1902 1902 SSSV Camco TRDP -IA -SSA' 2.810 PKR 7070 5947 SBR Otis 3.000 379 -7080, 7079 5954 PKR Otis 'RH' 2.970 7308 6122 NIPPLE AVA 'BPL' Landing Nipple 2.750 7308 6122 SLEEVE AVA; BPI SLEEVE W /(4) 1/4" PORTS SET ON 6/19/01 2.310 7317 6128 PKR Otis 'WD' 4.000 7333 6140 NIP Camco 'D' Nipple NO GO 2 250 7341 6146 SOS Brown 2.441 Perf 7342 6146 TTL 2.441 166 -7258) General Notes Perf - Date Note 280 -7288) 5/22/2002 SSSV hydraulics are disconnected at the tree. The SSSV is NOT locked out. 1 1 1 PKR 317 -7318, 7 NIP 333 -7334, II Perf L_ W3-7430) _y Perf �_ 152 -74901 ■ • • ConocoPhillips Alaska, Inc. Kuparuk Well 3B -01 (PTD 185 -056) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc., proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue water only injection with known annular communication for Kuparuk injection well 3B -01. Well History and Status Kuparuk River Unit well 3B -01 (PTD185056) was drilled and completed in April 1985 as a WAG injection well. 3B -01 was converted from MI injection to Produced Water on 01/08/07. On 07/02/07 the well was shut in after discovering a shallow surface casing leak which was reported to AOGCC on 07/03/07. Diagnostics identified a leak in the surface casing 50" from the OA annular valve. CPAI intends to excavate and patch the surface casing with a sleeve patch. Additional diagnostics performed on 10/14/07 confirm Production casing and tubing integrity with a passing MITIA to 3000 psi as well as wellhead seal integrity based on passing tubing and inner casing pack off tests. Barrier and Hazard Evaluation Tubing: The 3.5" 9.3 # J -55 tubing has integrity to the packer at 7079' MD based on a passing MITIA performed on 10/14/07. Production casing: The 7" 26# J -55 production casing has integrity to the packer at 7079' MD based on the MITIA described above. The well passed a witnessed, 4 year MITIA on 6/08/2007. Surface casing: The well is completed with 9 -5/8" 36# J -55 surface casing with an internal yield pressure rating of 3520 psi. The surface casing is set at 3357' MD (3252' TVD). After drilling out the surface casing and setting the production liner a cement shoe was pumped on 4/22/1985. 250 bbls of cement were bullheaded down the OA followed by 55 bbls of arctic pack. The cement shoe was tested to 1000 psi at the time of the cement job. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second r ba raer: The production casing is the secondary barrier should the tubing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing, production casing, or surface casing it will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut -in of the well. T/I plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. NSK Problem Well Supervisor 10/20/2007 • • Approved Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed); 2. Perform a passing MITIA every 2 -years as per AOGCC criteria (0.25 x tvd @ packer, 1500 psi minimum); 3. Submit monthly reports of daily tubing & IA pressures and injection volumes; 4. Shut -in the well should MIT's or injection rates and pressures indicate further problems; 5. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification. NSK Problem Well Supervisor 10/20/2007 2 3B-ol PTD # 185-056, notice surface casing leak Page 1 of 1 Maunder, Thomas E (©dA) From: NSK Problem Weil Supv [n1617@conocophillips.com} Sent: Tuesday, July 03, 2007 5:34 AM To: Regg, James B (DOA}; Maunder, Thomas E (DOA} Subject: 38-01 PTD # 185-056, notice of surface casing leak Attachments: 38-01 90 day TIO.jpg; 3B-01.pdf Jim & Tam, Yesterday afternoon we discovered a surface casing leak on 3B-01, PTD # 185-056, produced water injector. The surface casing failed during a pre corrosion inhibitor /sealant MITOA. Leak depth has been identified as approx 50 inches down from the OA valve. T/l/0- 2800/400/0 The well was shut in 7/2 @ 17.03 and the tubing was freeze protected. Immediate action will be to install a pit liner, apply for an AA to return the well to injection and pursue repair via excavation. The well passed a State witnessed MITIA, (John Crisp) on 6/8!07 confirming two competent barriers from the formation. Please let me know if you have any questions. Perry Klein Problem Well Supervisor office (907} 659-7224 CeN (907} 943-1244 Pager (907} 659-7000 x909 n 1617@conocophitlips.com «38-01 90 day TIO.jpg» «3B-01.pdf» ~d ~. v~~ ~~~~ ~~~ i2ii v2oo~ TRN ANNL 30 Sr_ SC 3000 2700 2400 2100 1800 1500 1200 900 600 300 0 ---------- - ---------------------------------------- - -------------------- PLOT °:i"PART TIME MINOR TIME 04-APR-07 05:40 MAJOR TIME WEER TAG ~T~ISE WL3D-01-CHORE SCRATCH 16 SCRATCH_16 SCRATCH_16 SCRATCH_16 DESCRIPTION FLOW TUBING CIiORE FLOW TUBING PRESSURE FLOW TUBING TEMP INNER AN27ULUS PRES OUTER ANNULUS PRES PICK TI1[E: ('t..0'I~ ()iDt?~3°3'ICDit F'I.Q",~" ?~.ND TIME. +p2160:00:00 HRS 03-JUL-07 05:40 7 03:47:2 5 - ~~ ~~~ 7~7~'~~a DRILLSITE WELL PREY WELL ??????? • 3B O1 ??????? ~ NEXT WELL 7???7?7 ??????? ENTRY TY('f•" OPERATOR ??????? OPERATOR VERIFIED ?????7? ~ :;`t`~TEM AiJ"Ci3 f~tTTRY ??????? ~ BOTH J~hINULUS i~RESSURE TRENDS WELL NAMk: WLRRU3B-O1 . . Regg, James B (DOA) From: Sent: To: Subject: NSK Problem Well Supv [n1617@conocophillips.com] Monday, October 22, 2007 9:22 PM Regg, James 8 (OOA) MIT KRU 38-01 10-14-07 PTO # 185-056 ....---;¡ (o\~~1 D 7 f.--e11 Attachments: MIT KRU 38-01 10-14-07.xls MIT KRU 3B-01 10-14-07.xls (22... «MIT KRU 3B-01 10-14-07.xls» Jim, Enclosed is a MITIA for 3B-01 PTD # 185-056, produced water injector. I've submitted a request for administrative approval to place 3B-01 back on injection that references the enclosed MIT. You should receive the request in the mail shortly. Let me know if you have any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com SGANNED NOY 012007 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us ,.J t--'3/i) 1 ?eft I U\ OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparukl KRU /38-01 10/14/07 Greenwood None Packer Dep.th Pretest Initial 15 Min. 30 Min. We1l13B-01 I Type Inj. I N TVD / 5,954' Tubing 1400 1400 1400 1400 Interval 0 P .T.D.!1850560 I Type test I P Test psil 1500 Casing 520 /3000 2940 2920 P/FI P Notes: MITIA for AA aplication. Not witnesed. OA 0 0 0 0 Weill I Type Inj. I TVD I Tubing Interval p.T.D.1 I Type test I Test psi! Casing P/F Notes: OA Weill I Type Inj. I TVD I Tubing Interval I p.T.D.1 I Type test I Test psi! Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval P.T.D.I I Type test! Test psil Casing p/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I P.T.D.I I Type test! Test psil Casing P/FI Notes: OA Weill Type Inj.1 I TVD I Tubing Interval P.T.D.I I Type testl I Test psi! Casing P/FI Notes: OA D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT KRU 3B-0110-14-07.xls l\fEMORl~NDUM . State of Alaska . "\Iaska Oil and Gas Conscrvation Commission TO: Jim Regg PJ. Supeniso " 0\ TE: IJcsda\ June 12" 2()(!7 í:"¡ ", StB.JECT: "kc!unlc:d Integllt\ !-es!ò ERO\!: John Crisp Petroleum Inspector KLPARljK RIV L~IT 38-01 ì tb Ç-D S-b Src: Illsp~ctür Rcviewed By: P.I. Suprv.~B2-· .. Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 38-01 API Well Number: 50-029-21318-00-00 Inspector Name: John Crisp Insp Num: mitJCr070612131250 Permit Number: 185-056-0 Inspection Date: 6/8/2007 ReI Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~- ~--~--~ -~ . -~-_._--- .~----_._; --- ---~-~--- ~_...._--_. -- -- . i Well I 38-01 ;Type Inj. w I TVD W54 IA 1460 3000 I 2950 2930 ~--_.~--~-_._~_._----;----~----------,-----------~------._- ~ --....-...---.--.-....-.--.- - -r- .-- ~----~-~-~--_._._------ ~_.- ----- P.T.D: 1850560 ,TypeTest . SPT' Test psi 1500 OA 230 340 340 I 340 ------_..._---~----- --- ~_. --- ----- --------- ---- --- -_.- ~_. ____ m____ - - - Interval 4YRTST PIF p Tubing' 2350 2348 2348 2347 " --_._-- ---------------- ------------------------ ------- ---.-.--..- ~- Notes: 1.5 bbl's pumped for test. iCANNED JUN ~ 1 2007 Tuesday. June 12. 2007 Page I of I ~'- Œ,\ &90- J LJ 9cól-Cft 12/08/03 Schlumberger NO. 3057 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk (' Well Log Description Date CD BL Color Job # ',' 3B-01 $C. ::C5-rlCj( INJECTION PROFILE 11/24/03 1 1 L-09 ,c ¡O--Q"3L, LEAK DETECTION LOG 11/26/03 1 1C-119 "", ( ~{"'i~Q INJECTION PROFILE 11/27/03 1 1 C-121 ~ ~ I--~IY,¡) INJECTION PROFILE ~ 11/30/03 1 1 D-11 OA 10709648 US IT - \')~i ~\. - (,-~ \õ ~~ç¿~',,-c.~\ ì\....()7-tO"'::õ) 10/31/03 1 U 1 D-140L 1 10709639 USIT \ 10/22/03 1 2P-432 ~C.N"rT1 SLIM SONIC LOGGING TOOL 11/21/03 1 \ 2P-432 10687658 USIT 11/16/03 1 ~~r 'en.. ILl "'" 5 "L-. V ü,..... ø v "'- 1,./ ( - . SIGNED:--"'~ L~-'- t "';'":\"'""'- \. ( 0 ~ ~ /'{'\ DEC 12 2003 DATE: Alaska Oil & t;ias Cons. Lommis8'ton Anchorage Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ß~ \'\\. ~ ~(Ç;AI~~~~f DEC ~] @ 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 / UNIT/PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/3B 06/05/03 Arend/Brake - APC Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. We, 13B-01 I Typelnjl Sp I T.V.D. 15954 I Tubingl ~01 ~3~01 ~01 235ol,nterva, I ¢ P.T.D, I1850560 Type Test TestpsiI 1500 I Casing I 12501 22501 22001 22001 P/F . Notes: P.T.D. li850750 TypeTest TestpsiI 1500 I Casing I 13501 20751, 20501 20501 P/F Notes: P.T.D. I1850770 TypeTest Test psiI 1500 I Casing I 7501 22001 21501 21501 P/F Notes: P.T.D. I1851160 TypeTest Test psiI 15o0 I Casing I 13501 20001 20001 20001 P/F Notes: P.T.D. I1850250 I. ,Type Test Test psiI 1500 1CasingI 14001 255oI 25ooI 25ooI P/F Notes: P.T.D. I1850260 Type Test Test psiI 1500 I Casing I 13001 20251 20001 20001 P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 2003-0605_MIT_K RU_3B-16.xls 7/10/2003 kRU MITs Subject: KRU MIT's Date: Fri, 6 Jun 2003 15:28:32 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: bob_fleckenstein@admin.state.ak.us, tom_maunder~admin.state.ak.us, jim_regg@admin.state.ak.us CC: "nl 617" <nl 617~conocophillips.com> Attached are the 4 year cycle MIT Results for 3B and 3F. Please call with any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: MIT KRU 3F 06-05-03.xls) (See attached file: MIT KRU 3B 06-05-03.xls) [~MIT KRU 3F 06-05-03.xls Name: MIT KRU 3F 06-05-0~.xls il Type: EXCEL File (application/msexcel) I Encoding: base64 ~,~MI.T_ KRU 3B 06-05-03.xls Type: EXCEL File (application/msexcel) I Encoding: base64 ? I of 1 6/25/2003 4:37 PI~. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU: Jim Regg "~¢',~',~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector DATE: June 5, 2003 SUBJECT: Mechanical Integrity Test Conoco Phillips 3B Pad KRU NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI3B-01I Type,nj.I s I T.V.D. I 5954 I Tubing12350 12350 12350 I 2350 I,nterva, I 4 P.T.D.I 185-056 ITypetestl P ITestpsil 1489 ICasingI 1250I 2250I 2200I 2200I P/F I P Notes: We,I3B-o5IType,~J.I G I T.V.~. I~ I Tu~,n,I ~00 I ~00 I~00 I~00 I,nterv~,l 4 P.T.D.I 185-075 ITypetestl P ITestpsil 1484 ICasingI 1350I 2075I 2050I 2050I P/F I 13 Notes: P.T.D.I 185-077 Notes: We,,I ~-~ I P.T.D.I 185-116 Notes: WellI P.T.D.I Notes: WellI 3B-16 P.T.D.I 185-026 'Notes: ' I Type testI P I Testpsil 1479 I CasingI 750 I 2200 I 2150 I 2150I P/FI P I I T~,~,~i.I ~ I ~.V.D. I~ I Tu~i~ I ~0 I ~0 I ~0 I~0 I Interva, I 4 TypetestI P ITestpsil 1436 I Casingl 1350I 2000I 2000I 2000I P/F I 13 185-025ITypetestl P I Testpsil 1442 I CasingI 1400I 2550I 2500I 2500I P/F I 13 I TYPe'ni-I ~' IT.v.D. I 5790 I Tubing I ~0 I ~0 I~0 I~0 I,nterva, I 4 I TypetestI P ITestpsil 1448 I Casingl 1300I 2025I 20o0I 2000I P/F I ~P 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 Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= ,Other (describe in notes) Test's Details I traveled to Conoco Phillips 3B Pad in the Kupamk field and witnessed the routine 4 year MIT's on the above listed 6 wells. The pretest pressures were observed and found to be stable. The standard annulus pressure tests were then performed with all wells demonstrating good mechanical integrity. M.I.T.'s performed: _6 Number of Failures: 0 Attachments: Total Time during tests: 4 hours CC: MIT report form 5/12/00 L.G. 2003-0605 MIT KRU 3B-16 cs.xls 6/24/2003 STATE OF ALASKA '- ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4500' FNL, 850' FEL, Sec. 16, T12N, R9E, UM At top of productive interval 1269' FSL, 1436' FWL, Sec. 16, T12N, R9E, UM At effective depth At total depth 3997' FNL, 4198' FEL, Sec. 16, T12N, R9E, UM Perforate _ Other_X WI to WAG Injection 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service__X (asp's 518179, 5991897) (as/o's 514828, 5992393) 6. Datum elevation (DF or KB feet) RKB 85 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3B-01 9. Permit number / approval number 1 85-056 / 10. APl number 50-029-2131 8 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 110' SURF. CASING 3272' PROD. CASING 7592' 7690 feet 6405 feet Plugs (measured) feet Junk (measured) feet Size Cemented Measured Depth True vertical Depth 16" 278 sx PF "c" 110' 1 10' 9-5/8" 95o sx AS HI & 3OO sx Class G w/' 3357' 3253' 7" 375 sx C}ass G 7677' 6396' Perforation depth: measured 7166-7258; 7280-7288; 7403-7430; 7452-7490 true vertical 6018-6085; 6101-6107; 6191-6211' 6228-6256 Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 9.3#, J-55 Tbg @ 7326' MD; 2-7/8",6.5#, J-55 Tbg @ 7342' OTIS 'RH' @ 7079' MD; OTIS 'WD' @ 7317' MD; CAMCO 'TRDP-1A-SSA' (LOCKED OUT FLAPPER 11/20/94) @ 1902' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 3751 2410 Casing Pressure 180 Tubing Pressure 2768 35O 3424 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service _X WAG Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /.~.~¢ ~_~ ¢~.~~,~,¢~/~;~'~¢-~_l. itle Production Engineering Supervisor Jeff A. Spencer Questions? Carl Jeff Spencer 659-7226 Date Prepared by Robert Christensen 659-7535 BFL Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 3B-01 ..... DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 8/13/01 I Commenced EOR Injection I I STATE OF ALASKA ALAS .... OIL AND GAS CONSERVATION COM,... ,.'SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~J Plugging [] Perforate [] Pull tubing Alter Casing ~ Other ~ 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box ].00360, Anchorage; AK 99510 4. Location of well at surface 776' FSL, 852' FEL, Sec. 16, T12N, RgE, UN 5. Datum elevation (DF or KB) RKB 85' 6. Unit or Property name K~Jnar~Jk River Ilnit 7. Well number 3B-1 At top of productive interval 1269' FSL, 1436' FWL, Sec. 16, At effective depth 1278' FSL, 1:1.46' FWL, Sec.16, At total depth 1280' FSL, 1079' FWL, Sec. 16, T12N, R9E, UM T12N, R9E, UM T12N, R9E, UM 8. Approval number #7-3 9. APl number 5O-- 029-21318 10. Pool Kuparuk River Oil Pool 11. Present well condition summary_ Total depth: measured 7690' ~.ID true vertical6404' TVD feet feet Plugs (measured~!One Effective depth: measured 7589' HD true vertical6329' TVD feet feet Junk (measured) None Casing Length Size Structural Conductor 110' 16" Surface 3357' 9-5/8" x x x X~'O(t~.krRC.~t e Production 7677' 7" xxxx xxxx Perforation depth: Feet Cemented Measured depth True Vertical depth 278 SX PF "C" 110' MD 950 SX ASIiI 3357' MD & 300 SX Class G 110' TVD 3252' TVD 6395' TVD 375 SX Class G 7677' MD measured 7166'-7258' MD, 7280'-7288' MD, 7490'-7452' MD, 7430'-7403' MD true vertical6017'-6085' TVD, 6101'-6107' TVD, 6256'-6227' TVD, 6211'-6191' TVD Tubing (size, grade and measured depth) 3½" J-55 9 4. lb/ft Tail ra 7342' MD Packers and SSSV (type and measured depth) OTIS RH ¢ 7079'; OTIS WD @ 7317'; CAMCO TRDP-1A @ 1902' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf 700 BOPD 1050 MOFPD Water-Bbl Casing Pressure - BWPD 200 psig 4000 BWPD 1600 psig Tubing Pressure 120 psig 17f')fl n~ i n ! 13. 14. Attachments Converted from oil producer to water injector on 1/23/87 Daily Report of Well Operations ~ Copies of Logs and Surveys Run 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Sr. Operations Engineer Signed /?L2fL~.'~ Form 10-404 Rev. 124-85 Date 2/25/88 Submit in Duplicate /'~- APrCO Alaska, Inc. Subsidiary of Atlantic Richfield Company W~LL I PBDT ~-~-1_ I 75'7~/ C'r"NTRACTOR, REMARKS WELL SERVICE REPORT GO o--~ [--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. I Chill Factor I Visibility Report °F °F miles IWind Vel. ATTACIIMENT 1 PAGE 3 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE 4 - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl NUMBER NUMBER 50-029 '"~3B-O1 J 21318 '""-~ 3 B- 07~''' 21337 '"'"~ 3 B- 12~'/' 21370 30-02 21414 ~"~3F-03~ 21448 3J-04 21400 '"'~3J-05j 21436 "~ 3J-08 '-'"' 21439 3J-13 21495 3J-16 21498 /.:-/; //-- DATE OF DATE OF DATA TYPE REASON FOR INITIAL PROFILE/ PROFILE/ PROFILE/ INJECTION SURVEY SURVEY SURVEY WELL COMPLETION 01/23/87 05/23/87 SPINNER INITIAL A&C SS 01/23/87 05/22/87 SPINNER INITIAL A&C SS 01/24/87 05/21/87 SPINNER INITIAL A&C SS 01/09/86 06/22/87 SURVEY FOLLOWUP A&C SS 05/24/87 04/01/87 05/28/87 05/28/87 03/01/87 03/31/87 SPINNER SURVEY SPINNER SPINNER SURVEY SURVEY N TIAL N TIAL N TIAL N TIAL N TIAL N TIAL 01/21/87 05/21/87 02/02/87 02/02/87 02/02/87 02/02/87 A&C SS A S A&C SS A&C SS A S A S ZONES TAKING WATER A&C A&C A&C A&C A&C A A&C A&C A A I NJ ECT I ON BNPD 2530 A SAND 1240 C SAND 1927 932 1072 ! / 1 RECEIVF. D STATE OF ALASKA ALAS,,.. OIL AND GAS CONSERVATION COMN,~,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon F~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing [] Time extension ii! Change approved program ~ Plugging [] Stimulate, ~, Pull tubing,~ Amend order ~ Perforate D Other 2. Name of Operator 5. ARCO A1 aska, Inc RKB 3. Address 6. ?0 Box 100360, Anchoraqe, AK 99510 Kup 4. Location of well at surface 7. 776' FSL, 852' FEL, Sec. 16 TZ2N, RgE, UM 3B- At top of proi:luctive interval ~ 8. Datum elevation (DF or KB) 85 Unit or Property name aruk River tJnit Well number 1 Permit number Permit #85-56 9. APl number 50-- 029-21318 feet 1269' FSL, 1436I Ateff~ctive dep. th 1278 FSL, 1146' At total depth 1280' FSL, 1079' 11. Present well condition summary Total depth: measured 7690' MD true vertical6404, ND FWL, Sec.16, T12N, R9E, UM FWL, Sec. 16, T12N, R9E, UM FWL, Sec.16, T12N~ R9E, UM 10. Pool KuDaruk Rivm_r O'il Pnnl , feet feet Plugs (measuredNolle Effective depth: Casing Structural Conductor Surface X X X >l~t, eXOo]~ti~te Production xxx~Arxxxx Perforation depth: measured 7.~g9' MD true verticalneSS, MD Length Size IlO' 16" 3357' 9-5/8" 7677' 7" feet feet Junk (measured)Nolle Cemented Measured depth ~ue Vertical depth 278 SX PF"C" 110' MD 110' TVD 950 SX ASIII 3357' MD 3252' TVD & 300 S× Class G 375 SX Class G 7677' MD 6395' TVD measured 7166'-7258' MD, 7280'-72881 MD, 7490'-7452' MD, 7430'-7403' MD true vertical6017'-6085' TVD, 6101' -6107' TVD, 6256'-6227' TVD, 6211' Tubing (size, grade and measured depth) 3½", J-55, 9.4 lb/ft, Tail @ 7342' Packers and SSSV (type and measured depth) Otis RH @ 7079'; Otis Wll fa 7317'_; Camco TRDP-!A @ !902' 12.Attachments Description summary of proposal ~ Detailed operations program I%, Convert well from oil producer to water inj~r, tnr 13. Estimated date for commencing operation January 10, 1987 BOP sketch -6191' 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 · .~ .t~ ,- ~.,t" /~'~ Title Sr. Operations Engineer Signed /'~1 6t-~ .../) ..~'I~-L-.~ ,.. .. ¢..~ ~ J Commission Use Only Dal]a?./23/86 Conditions of approval .. Approved by .~,~; Form 10-403 Rev i'~_~-1-t~'~'"''; Notify commission so representative may witness [] Plug integrity [] BOP Test ,,~ Location clearance .¢~ to-veal Co~y Commissioner by order of the commission Date Submit in triplicate ARCO Alaska, Inc. Post Office BOX 100360 Anchorage, Alaska 99510-0360 LFeleplione 907 276 i2i5 September 24, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: Enclosed are Well Completion Reports for the following wells: 3B-1 3B-5 3B-2 3B-6 3B-3 3B-8 3B-4 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU11/L126 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~. ~ AND GAS CONSERVATION Co~ _ ilSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO A]aska, Inc, 85-56 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21318 4. Location of well at surface 9. Unit or Lease Name 776' FSL, 852' FEL, Sec.16, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1269' FSL, 1436' FWL, Sec.16, T12N, RgE, UM 3B-1 At Total Depth 11. Field and Pool 1280' FSL, 1079' FWL, Sec.16, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKB ADL 25633 ALK 2566 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 04/08/85 04/14/85 04/14/85* N/A feet MS L 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 7690'MD,6404'TVD 7589'MD,6329'TVD YES F~X NO []I 1902 feet MD 1600' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP, FDC/CNL, Cal, C/BL/VDL, Gyro ~23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 278 sx PF "C" 9-5/8" 36.0# J-55 Surf 3357' 12-1/4" 950 sx AS III & 300 sx :lass "G" Performed top job w/100 sx AS I 7" 26.0# J-55 Surf 7677' 8-1/2" 375 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) 7490' - 7452' 3-1/2" 7342' 7079' & 7317' 7430' - 7403' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7288' - 7280' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7258' - 7166' w/12 spf, 120° phasing See attached Addei~dum¢ dated 7/26/85. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,4!ask'a 0ii & G,~6. Coi~s, Form 10-407 * NOTE: Tubing was run and the well perforated on 6/6/85. GRU11/WC05 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 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 Upper Sand 7162' 6014' N/A Base Upper Sand 7259' 6085' Top Lower Sand 7379' 6173' Base Lower Sand 7557' 6305' : 31. LIST OF ATTACHMENTS Adrl~nd,~m ." -- _ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · , Signed 6/~4 ~7')(_2 ~ Title Associate Engineer Date _ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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 '" ADDENDUM WELL: 5/13/85 6/19/85 3B-1 Rn CBL/VDL & GCT. Frac well w/392 bbls gelled diesel in 8 stages w/lO00# 100 mesh & 15,000# 20/40 sand. Drilling ~uperintendent Alaska Oil & dias Cons. Con-mission . , ..~. ~ ~, D~te ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 9, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3B-1 Dear Mr. Chatterton: Enclosed is a copy of the 3B-1 Well History (completion details) to include with the Well Completion Report, dated 07/03/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L49 Enclosure Alaska 0i! & Gas 0o~s, Oommission Anchoragr, AI4CO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Companyv'~' Well History - Initial Report - Daily Inatructlonl: Prepare and submit the "Initial Ral:lort" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River lCounty, parish or borough iState · North Slope Borough Alaska IL ..... Unit IWell no. ADL 25633 '-- 3B-1 ITRle Complete Auth. or W.O. no. AFE 604313 Roll'N 4 AP1 50-029-21318 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete I ARCO W.I. IDate 6/2/85 IH°ur 1030 hrs. IPri°r status if a w'O' Date and depth as of 8:00 a,m. Complete record for each day reported 6/01/85 thru 6/03/85 6/04/85 6/05/85 6/06/85 56.24% 7" @ 7677' 7588' PBTD, 7690' TD, Bleed press Wt. 10.2 ppg NaC1/NaBr Accept rig @ 1030 hrs, 6/2/85. ND tree, NU &tst BOPE. RU DA, perf "A" sand f/7452'-7490' MD & 7403'-7430' MD w/4" guns, 4 SPF, 120° phasing. 'Perf "C" sand f/7280'-7288' MD & 7238'-7258' MDF Well flowing. SI & monitor same. Press stabilized @ 200 psi. SI choke ln. RD DA. Wt up mud. 7" @ 7677' ~ - 7588' PBTD, 7690' TD, CBU 10.6 ppg NaC1/NaBr Pmp 176 bbls 10.6 ppg brine. TIH w/3~" tbg to 7527', CBU. 7" @ 7677' 7588' PBTD, 7690' TD, Rn 3½" compl 10.6 ppg NaC1/NaBr Displ well to brine. RU WL, RIH w/,~" csg guns, 12 SPF, 120° phasing. Perf f/7238'-7166'. RIH w/pkr & tailpipe assy. Set @ 7311'. 7" @ 7677' 7588' PBTD, 7690' TD, POH w/std'g vlv 10.6 ppg NaC1/NaBr RIH w/3½" completion. Set pkr. Pressure did not hold. RIH w/std'g vlv, set @ 7346'. Press tbg to 2500 psi, bled to 3000 psi. Press ann to 2500 psi, bled to 2000 psi. RIH to retry std'g vlv. The above is correct Signature For form preparation and' ~rJbutJon, see Procedures Manual, Se~'tion 10, Drilling, Pages 86 and 87. Date Title J 6~20/85 Drilling Superintendent AR3B-459-1-D Number all daily well history forms consecutively ge no. as they are prepared for each we . Pa 1 ARCO Oil and Gas Company'v"~' ' Daily Well History-Final Report Inslructioes: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or welt 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 operabon it space is available. I Accounting cost center code Dislrict ] State Alaska North Slope Borough .. Alaska I County or Parish Lease or Unit I Well no. Kuparuk River ADL 25633 I 3B-1 Auth. or W.O. no. |Title AFE 604313 I Completion API $0-029-21318 Roll'N 4 Operator ARCO Alaska, ]:nc. Spudded or W.O. begun Complete 6/07/85 Date and depth as of 8:00 a.m. AR.Co. W.I. 56.24% Date 6/2/85 Complete record for each day reported I otal number of wells (active or inactive) on this pst center prior to plugging and bandonment of this well our 1030 hrs. Prior status if a W.O. 7" @ 7677' 7528' PBTD, 7690' TD, RR 7.2 Crude Redress std'g vlv & set in "D" nipple. Tst ann to 2500 psi. Tst tbg to 2500 psi. Shear PBR. Set BPV. ND BOPE, NU tree. Pull BPV. Set tst plug. Tst pack-off & tree to 300/5000 psi. Displ well dn ann w/30 bbls diesel, followed by crude. SITP = 550 psi. Tst SSSV; OK. Tst orifice; OK. Pull std'g vlv. Set BPV. RR @ 1700 hrs, 6/6/85. 7" Perm Pkr @ 7317' - '~" Nipple @ 7333' - TT @ 7342' Old TO Released rig New TO PB Depth 7690' 7528' PBTD 1700 hrs. Date 6/6/85 Kindofrig Rotary Classifications (oil. gas, etc.) Oil Producing method Flowing Potential test data Type completion (singie. dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature I Date Title /~-P~a~,o ~, ,~~/n - ._ I 6/20/85 Drilling Superintendent For form prepa ' lb tiDe, seeP .... d .... M .... ,. Section 10, i% .~., ~ ~ ~:? r¢~'" Drilling, Pages 86 and 87. ~ ~-- ~ ~ ~ AR3B-459-3-C ~ |as ~'&S,'~'re pre~a;~8 f$-r ~ch' well. consecutively no. Division of AllanticRichfieldCompany ARCO Alaska, Inc Posl Office r_,,.,-x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-20-85 TRANSMITTAL NO: 5294 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH RECEIPT AND RETUF~N ONE FINAL PRINTS / SCHbUMBERGER CET/CEMENT EVALUATIONS (ONE qZ-8 j CET LOG ~J2V-9/ CET LOG -~2H-14 -'~CET LOG OlR-7/CEMENT EVALUATION SIGNED COPY Of' THIS ARE THE FOLLOWING IT~4S. PLEASE ACKNOWLEDGE TRANSMITTAL. * OF EACH) 04-26-85 i<UN #1 ~400-9208 04-25-85 RUN #1 7000-7893 04-05-85 RUN #1 7400-E700 06-19-85 RUN #1 4500-7033 FINAL PRINTS / SCHLUMBERGER CBL'S .(ONE * OF EACH) 3B-1/~ 05-06-85 RUN #1 '~ 2U-11-"'~ 05- 03- 85 RUN #1 2U-10/05-03-85 RUN #1 J2U-9 ~ 05-02-85 RUN #i -~lQ-16 / 05-27-85 RUN # 1 5040-7563 ..... 8423 5500-6963 5850-80S9 4290-7018 i<ECEIPT ACKNOWLEDGED: 3PAE CURRIER iHEVRON ~ & M DIST~iIBUTION: DRILLING*BL W. PASHER L. JOHNSTON EXXON MOBIL PHILLIPS OIL NSK CLERK*BL J. RATHMELL ~E ~~,'" ..... ,.~:; Corm. Commissmri STATE OF ALASKA*BL SOHIO /SE UNION K. TU LIN/VAU LT* FI LMS ARCO Alaska. Im Post Office ~ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO:5292 RETUP~q TO: ARCO aLASKA, INC. KUPARUK OPERATIONS RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ENGINEERING TRANSMITTED RECEIPT AND KUPARUK WELL lB-1. 05-3 lB-2. 05-3 ~'iB- 4. 05-1 HEREWITH ARE THE FOLLOWING ITEMS. pLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. PRESSURE REPORT--ENVELOPE FACE DATA 0-~5 CAMCO ~3B-15 05-28-85 OTIS 0-85 CAMCO ~, 3B-16-'- 05-28-85 OTIS 6-85 CAMCO "~ 3C-11- 07-29-85 CAMCO ~' 1C-4 1C-6-' -- 1D_ 8_~ --1H-3 --- 1Q_13-~ "1Q-14~' "-lQ- 15- "1%2-16 1R_5-~ 1R_6-? --1R_7~- "1R-8, '-2A- 2" ' '-2W-7' "'-2 V- 3 -~2~- 15" 3B-1 3B-2~-- 3B-3" '-3B-3' --3B-4- ~3B-5 -3B_6-- 3B-7-~ 3B-8.~ -..3B- 9~- -3B-11 -- 3B- 12 3B-13~ -3B-14 RECEIPT 07- 24- 8 5 CAMCO 07-25-85 CAMCO 07- 3 0- 8 5 CAMCO 07- 30- 85 CAMCO 06- 24- 8 5 CAMCO 06-23-85 CAMCO 06- 2 1- 8 5 CAMCO 06-21-85 CAMCO 07- 05- 85 CAMCO 07-06-85 CAMCO 07-06-8 5 CAMCO 07-08-85 CAMCO 07-04-85 OTIS 07-26-85 DRESSEI{ 07-11-85 OTIS 08-04-85 OTIS 06-14-85 ???? 06-14-85 CAMCO 06-28-~5 OTIS 06-15-85 CAMCO 06-15- 85 CAMCO 06- 26- 85 CAMCO 06- 26- 8 5 CAIn]CO 06- 28- 85 CAMCO 06- 27- 8 5 C~24CO 06-28-85 OTIS 07- 18- 8 5 CA~CO 07- 20 - 85 CAMCO 07-20-85 CAMCO 07- 21- 85 CAMCO 05-29-85 OTIS 05-29-85 OTIS ACKNOWLEDGED: BPAE* B. CURRIER CHEVRON* D & M* DISTRIBUTION: DRILLING W. PAShER L. JOHNSTON EXXON t, lPB I L* PHILLIPS OIL* NSK CLERK J. RATHMELL* STATE OF ALASKA* SOHIO* UNION* K. TULIN/VAULT ARCO Alasl(a. Inc. ~s a Subsidiary of AtlanlicRichfieldCompany ARCO Alaska, Inc. Post Office B ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 30, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent following wells at the Kuparuk River Field. notices Well Action 1G-2 Acidize 7/12/85 1R-5 Fracture 7/16/85 1R-6 Fracture 7/19/85 1 R-7 Fracture 7/17/85 1R-8 Fracture 7/17/85 2D-7 Acidize 6/21/85 2D-8 Acidize 6/21/85 2H-3 Acidize 6/21/85 2H-13 Fracture 7/23/85 2 X-5 Perforate 7 / 23 / 85 3B-1 Acidize 7/22/85 Date Performed on the :'ih If you have any questions, please call me at 263-4212. T. M, Drumm Kup~ruk Operations Coordinator TMD/kmc Attachment (Duplicate) RECEIVED ,qu o e ~'la~:a Oi~ .. (~ Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKAOIL AND GAS CONSERVATION COi~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION- 776' FSL, 852' FEL, SEC, 16, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 85 ' (RKB) 12. 7. Permit No. 85-56 8. APl Number 50- 029-21 318 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 3B-1 11. Field and Pool KUPARUK RIVER F! ELD I6. Lease Designation and Serial No. KUPARUK RI VER O I L ADL 25633, ALK 2566 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation ~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On July 22, 1985, the "C" sands of Kuparuk well 3B-1 were acidized improve production. The treatment consisted of 70 bbl of 12% HCL. Diesel was used for flushing and nitrogen to aid well cleanup. Prior to starting job, equipment was pressure tested to 4,000 psi. to RECEIVED Alaska OJ! & Ga~ Cl:-rts Ca,.':irnis~ior~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,~ ~'~~ Title KU PARUK The space below for Commission use OPERAT 10NS COORD ! NATOR Date 7/29/85 Conditions of Approval, if any' By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE~07-16-85 TRANSMITTAL NO:5249 RETURN TO: TRANSMITTED RECEIPT AND ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING . RECORDS CLERK ATO-1115B ~ - P.O. BOX 100360 . ANCHORAGE, AK 99510 ~ HEREWITH ARE THE FOLLOWING ITEMS.'/~/PPLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. OPEN HOLE (ONE * OF EACH) 3B-1 5" 2" 5" 2" 5" 2" 3B-2 / 5" 2" 5" 2" 5" 2" FINAL PRINTS/SCHL DIL/SFL-GR DIL/SFL-GR DEN/NEU DEN/NEU DEN/NEU DEN/NEU CYBERLOOK DIL/SFL-GR DIL/SFL-GR DEN/NEU DEN/NEU DEN/NEU DEN/NEU CYBERLOOK PORO PORO RAW RAW PORO PORO RAW RAW 04-13-85 04-13-85 04-13-85 04-13-85 04-13-85 04-13-85 04-13-85 04-20-85 04-20-85 04-20-85 04-20-85 04-20-85 04-20-85 04-20-85 RUN #1 3361-7666 RUN #1 3361-7666 RUN ~1 6950-7640 RUN #1 6950-7640 RUN ~1 6950-7640 RUN ~1 6950-7640 RUN ~1 6950-7617 RUN ~1 3857-8283 RUN ~1 3857-8283 RUN #1 6000-8260 RUN #1 6000-8260 RUN #1 6000-8260 RUN #1 6000-8260 RUN ~1 7600-8225 5" DIL/SFL-GR 2" DIL/SFL-GR 5" DEN/NEU 2" DEN / NEU 5" DEN/NEU 2" DEN / NEU CYBERLOOK PO RO PORO RAW RA%7 04-27-85 04-27-85 04-27-85 04-27-85 04-27-85 04-27-85 04-27-85 RUN #1 3242-6622 RUN 41 3242-6622 RUN 41 5850-6596 RUN ~1 5850-6596 RUN ~1 5850-6596 RUN 41 5850-6596 RUN 41 5850-6573 RECEIPT ACKNOWLEDGED: BPAE B. CURRIER CHEVRON D & M*BL DISTRIBUTION- DRILLING*BL ~. PASHER L. JOHNSTON EXXON MOBIL PHILLIPS OIL NSK CLERK*BL J. RATHMELL*BL DATE STATE OF ALASKA*BL SOHIO /SE UNION K.TULIN/VAULT*FILMS ARCO Alaska. ,nc. ~s a Subsidiary' of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office B. J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 22, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Cas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are our notices of intention to field well 2C-8 and to acidize 3B-1. If you have any questions, please call me reperforate Kuparuk at 263-4212. T. Mark Drumm Kuparuk Operations Coordinator TMD / kmc Attachment (In Triplicate) R C IVF-D jUL2 2198 Gas Cons. comm'tss~on Anchorage ARCO Alaska, Inc. Is a Subsidiary ol AllanticRichlieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COFviMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL[] COMPLETED WELL~ OTHER [] 2. Na/~pe/~a~SKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 776' FSL, 852' FEL, SEC. 16, T12N, RgE, tJM 7. Permit No. 85-56 8. APl Number 50- 029-21 318 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 3B-1 11. Field and Pool KUPARUK RIVER FIELD 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KUPARUK R! VER O I L 85' (RKB) I ADL 25633, ALK 2566 POOL 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing ]~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Per conversation with Harold Hedlund of AOGCC on 7/22/85 it is proposed that the "C" sand in Kuparuk well 3B-1 be acidized to improve production. The treatment will consist of 70 barrels of HCL with MSR100 and iron sequestering agent. 12% The acid is to be pumped by coil tubing nitrogen to aid well cleanup. Prior to be pressure tested to 4,000 psi. unit and displaced with starting work· equipment will Fluid Requirements- 12% HCL 70 BBLS Diesel 60 BBLS Nitrogen 2000 GALS ANT ICI PATED START DATE. JULY 22 · 1985 . ~-~ /~, ~ , .;.., . , 14''he'b:*r:i*hachef°reg°ingistrueand**ctt°thebest°fm~;Ti~;;*~"//,,, Z--. -~ ' ~'" - * ' -- - Date 7/22/85 Signed /////~'~ The space below for Commission use Conditions of Approval, if any: ITiiG, It~AL Slt~IIIEB Approved by Approved Copy ~#turn~ By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alas!ca 995!0-0360 Telephone 907 276 1215 July 3, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3B-1 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for 3B-1. I have not yet received the Well History (completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L48 Enclosures L o 9 Gas Cons, Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldC.ompany STATE OF ALASKA ALASKA ~.__ AND GAS CONSERVATION CC AISSION WELL COMPLETION OR RECOMPLETION R EPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-56 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21318 4. Location of well at surface 9. Unit or Lease Name 776' FSL, 852' FEL, Sec. 16, T12N, R9E, UM CA'ii©NSf Kuparuk River Unit At Top Producing Interval'J VE~I~?D ' 10. Well Number 1269' FSL, 1436' FWL, Sec.16, T12N, R9E, UM ~Sur~:. F__~j 3B-1 At Total Depth J B. ~.._,~_] 11. Field and Pool 1280' FSL, 1079' FWL, Sec. 16, T12N, R9E, UM' - Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKBI ADL 25633 ALK 2566 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116. No. of C°mpleti°ns 04/08/85 04/14/85 04/14/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. PIugBackDepth(MD+TVD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 7690'MD,6404'TVD 7589'MD,6329'TVD YES F~X NO [] 1902 feet MDI 1600' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP, FDC/CNL, Cal, CBL/VDL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE'WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 278 sx PF "C" 9-5/8" 36.0# J-55 Surf 3357' 12-1/4" 950 sx AS Ill & 300 sx ('.lass "G" Performed top .iob w/100 sx AS I 7" 26.0# J-55 Surf 7677' 8-1/2" 375 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) 7490' - 7452' 3-1/2" 7342' 7079' & 7317' 7430' - 7403' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7288' - 7280' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7258' - 7166' w/12 spf, 120° phasing N/A ' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE j~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED Alaska 0it & Gas Cons. Commission Form 10-407 * NOTE: Tubing was run and the well perforated on 6/6/85. TEMP/WCS0 Submit in duplicate Rev. 7-1180 CONTINUED ON REVERSE SIDE : . ';,..... . .. i GEOL. O~GIc. MARKERs · ",-" i-"- ': : ~_,- '. : :;'~- -.~ ' '. :_.-. " " ' :' ' :'? : :~ : "' ' '":'" ::'FORMATION'TESTS ' - '- '". · ... . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7162' 6014' N/A Base Upper Sand 7259' 6085' Top Lower Sand 7379' 6173' ,' ' Base Lower Sand 7557' 6305' · -. · .. . 31. LIST OF ATTACHMENTS Cyrn.~e~ple S~rvey (2 eopi~.s~ : 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · /~0 ~l~f)(~/ L~L~ Title Ass°clare Engineer Date Signed ____ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements · given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- 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 ARCO Alaska, Inc. Post Office Box 100360 Ar~choFage, Alaska 99510-0360 rfelephone 907 276 12i5 June 3, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3B-1 Dear Mr. Chatterton' Enclosed is a copy of the 3B-1 Well History to include with the Well Completion Report, dated 05/24/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L30 Enclosure cc' 3B-1 Well File ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED J U N 0 6 ]9~ Alaska 0ii & Gas Cons, Commission Anchorage ARCO Oil and Gas Company Well History- Initial Report- Daily Inmtructlons: Prepare and submit the "lnltls[ Report'' on the first Wedn.esday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River ICounty, parish or borough North Slope Borough Lease or Unit ADL 25633 Title Drill IState Alaska IWell no. 3B-1 Auth. or W.O. no. AFE 604313 Parker 141 API 50-029-21318 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 4/08/85 4/09/85 4/10/85 4/11/85 4/12/85 ARCO W.I. 4/8/85 1645 hrs. Complete record for each day reported 56.24% O MIRU. Accept rig @ O~hrs, 4/8/85. NU diverter sys. 16" @ 110' 1963', (1853'), TIH w/DD Wt. 8.9, PV 17, YP 35, PH 10, WL 18.4, Sol 5 Spud well @ 1645 hrs, 4/8/85. Drl 12¼" hole to 1963'. 16" @ "~79' 110' · (1416'), Rn'g 9-5/8" Wt. 9.3, PV 12, YP 16, PH 9.5, WL 14.1· Sol 8 DD, & surv 12¼" hole to ~9', 18 etd short trip, C&d, POOH. RU to rn 9-5/8" csg. 2183', 5.3°, N47.5W, 2183 TVD, 10 VS, 5N, 9W 2525',~ 15° N67.4W, 2519 TVD, 66 VS, 36N, 59W 2839', 25.~°, N74W, 2814 TVD, 173 VS, 67N, 162W 3345', 37.5°, N72.5W, 3245 TVD, 437 VS, 139N, 416W 9-5/8" @ 3357' 3840', (461'), Turbine drlg Wt. 9.0, PV 5, YP 7, PH 11.5, WL 16.6, Sol 4 Rn 77 jts, 9-5/8", 36#, J-55 HF-ERW BTC csg & lnd w/FS @ 3357', FC @ 3271'. Cmt w/950 sx AS III w/1/2#/sx cellophane. Tail in w/300 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. Cmt did not circ. ND diverter & perform 100 sx AS I top job. NU & tst BOPE. RIH, DO FC, tst csg to 1500 psi, DO cmt, FS + 10' new formation. Conduct formation tst to 12.6 ppg EMW. Drl 8½" hole to 3537', POOH f/turbine, RIH & drl to 3840'. 2957', 28.4°, N74.1W, 2919.30 TVD, 226.06VS, 81.29N, 213.23W 3345', 37.5°, N72.5W, 3244.72 TVD, 436.56VS, 139.23N, 415.89W 3502', 41.7°, N73.6W, 3365.69 TVD, 536.40VS, 168.32N, 511.64W 9-5/8" @ 3357' 5935', (2095'), Turbine drlg Wt. 9.2, PV 8, YP 7, PH 9.5, WL 12.2, Sol 7 Turbine drl & surv 8½" hole to 5935'. 3781', 43.3°, N71.3W, 3571.39 TVD, 724.30VS, 225.16N, 691.36W 4500', 43.6°, N80.5W, 4091.07 TVD, 1220.58VS, 350.73N, 1171.70W 5129', 43.8°, N82.3W, 4550.34 TVD, 1648.84VS, 412.03N, 1597.07W 5441', 43.2°, N82.2W, 4776.66 TVD, 1862.71VS, 440.99N, 1809.87W RE JUNo The above is correct Signature For form preparation and ~tr~utlon, see Procedures Manual, S~ctlon 10, Date 5/10/85 Title Alaska Oil & A~.q Cnn.q P, nrnmissior~ ,. ~,nchorage Drilling ~uperinten~en~ Drilling, Pages 86 and 87. 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 subm~lled also when operations are suspended i'or an indefinite or appreciable leng!h 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 reportirt9 the entire operation ~f space is avadaDle. Accounting cost center code District JCounty or Parish State Alaska I North Slope Borough Alaska Field ILease or Unit IWell no. Kuparuk River ADL 25633 3B-1 Auth. or W.O. no. ~Title AFE 604313 I Drill Parker 141 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and deplh as of 8:00 a.m. 4/13/85 thru 4/14/85 AR.Co. W.I. Date Complete record for each day reported API 50-029-21318 rTotal number of wells (active or inactive) on this Icost center prior to plugging and 5 6.24?0 labandonment of this well I IHour I Prior status if a W.O. 4/8/85 ! 1645 hrs. I 7" @ 7677' 7690', (1755'), RR Brine ;~ Drl & surv 5935'- ', TOH & LD turbine. PU rotary assy, TIH, drl 7208'-7680', C&C f/short trip; no problems, TOH. RU Schl, rn DIL/SFL/GR/SP/CAL f/7676'-3361', FDC/CNL f/7676'-6000', RD Schl. TIH & drl 7680'-7690', C&C well, POOH & LD DP. Chg rams to 7", tst to 3000 psi. RU & rn 178 jts, 7", 26#, J-55 BTC w/FS @ 7677', FC @ 7588'. KC1, .8% D-60 & .2% D-46. w/3000 psi; OK. ND BOPE & wellhead. Tst pack-off to 4/14/85. 5749', 43.5°, N82.5W, 5000. 6094', 44.8°, N85.4W, 5248. 6504', 43.1°, N83.7W, 5543. 6847', 42.8°, N84.5W, 5794. 7133', 42.8°, N85.7W, 6004. 7610', 40°, N81.7W, 6362. C&C well. M&P 375 sx C1 "G" w/3% Drop top plug & displ. Bump plug set slips. Cut off csg & NU 3000 psi; OK. RR @ 2400 hrs, 63 TVD, 2073.22VS, 469.14N, 2019.42W 17 TVD, 2311.76VS, 494.47N, 2258.39W 35 TVD, 2593.85VS, 521.50N, 2541.66W 41 TVD, 2825.76VS, 545.52N, 2774.13W 26 TVD, 3018.14VS, 562.12N, 2967.74W 06 TVD, 3331.43VS, 596.74N, 3281.28W OIdTD JNewTD 7690' (4/14/85) Released rig Date 2400 hfs, 4/14/85 PB Depth Kind of rig Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s} Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form-pr~parati .... d f:~'tributiol see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office B~,,. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 i215 Hay 28, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3B-1 Dear Mr. Chatterton: Enclosed is the Well Completion Report for 3B-1. I have not yet received a copy of the well history, but when I do, I will forward a copy to you. Also, tubing details will be submitted when the well is completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L09 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ,, .... AND GAS CONSERVATION CC,_ _:VIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I-XIX ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-56 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21318 4. Location of well at surface 9. Unit or Lease Name 776' FSL, 852' FEL, Sec.16, T12N, R9E, UM (Approx) Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 3B-1 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKBI ADL 25633 ALK 2566 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116' No' of Completions 04/08/85 04/14/85 04/14/85I N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7690'ND 7589'MD YES [] NO I-~XI N/A feet MD 1600' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP, FDC/CNL, Cal 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 278 sx PF "C" 9-5/8" 36.0# J-55 Surf 3357' 12-1/4" 950 sx AS Ill & 300 sx ;lass "G" Performed top .lob w/100 sx AS I 7" 26.0# J-55 Surf 7677' 8-1/2" 375 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) None N/A 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "~' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Alaska 0it & Gas Cons, C0mmlssi0r~ Form 10-407 TEMP/WC16 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE _. . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR; and.time of each phase: ' - . · . N/A N/A .:..: ~- '.- '. :)~;~. :;. .,,-:r.- , i,':;;'.h~' :;. . .-' · · -~ . , ,,: t, - ~?-:' : c" - · . · : : · ' ;, ,'., ~ !..~: - .. 31. LIST OF ATTACHMENTS .~ '~-~ ~. . Nnn~ . :., , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ,~L~~ 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 10407 $ UB-$ URFA CE DIRECTIONAL SURVEY ~ UIDANCE ~]ONTINUOUS ~-f~ OOL Company Well Name ATLANTIC RICHFIELD COMPANY 3B-1 (77,6' FSL, .85,2' FEL,. S16~ T12N~ R9E~ UM) Field/Location K~A~ NORT~ SLOPE, A~ASr, A Job Reference No. 70454 Lo~ed By: HALFACRE/KOZUSKA RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Date 06-05-85 Computed By: KRIrWELL C~CT PIRECTTUNAI, SURVEY CIISTOMER LISTING FOR ALASKA, INC. KUPARUK NOR'IH ~bDPE,AbASKA SURVEY DATF: 06-MAY-B5 ~ETHODS OF CO~PUTATIIDf~ TUOb hO¢A'.['IUH: TANGENTIAL- averaged deviation and azimuth TNT~RPOL~'~T()N: T,.LNt~ R UFHTJCAI, SDiC'I'IO~I: ttnRIz, DIS'f, PROJECTED flHTC) A TARGET AZIMUTH Of' NORTH 77 DEG 0 MIN WEST Ctq~PUTATION DI~TW: S-JUN-RS ARCO AEAfiKA, TNC. 3R-1 KIIP~RIIK NORI'H 8I,UPE,AI~ASKA PACE DATE .OF SURVEY: 06-MR¥-85 KELbY BUSHING FLEVAT/ON: ENGTNEER: HALFACEE/PEPPEL It4TFRPOI..ATED VAI,U?S F'thR EVEN l OO FEET OF MEASURED DEPTH TRUE SHR-SE;~ CnURSE qEA$I)RED VERTICAl. VEWTICRL DEVTAq'ION AZI~lJTH DEPTH DEPTH DEPTH DEG I4TN DFG MIh' 0.0o O.OO -85.00 0 0 ~ o 0 E 100 O0 100.00 1K,O0 0 17 ~ 14 27 F 200'00 200.On 115,00 0 lq ~ 71 57 w oo2 o ]oo.oo 5.oo o s r 400 oo 4oo. ls.oo o . 500'00 409, 414,99 0 16 N 47 23 E 600:00 509.99 ~14,q9 0 19 k: 43 q E 70o.o0 6q9.9~ 61t.99 0 1~ N K2 50 E ~O0.nO 709 99 714,q9 0 11 ~ 77 57 ? 900.o0 899:9q 814,q9 0 lq S 1.5 4 E 1000.00 9gq.gq ql4.q9 llO0.nO 1099.9o 1014.99 l?On. OO 1199 9R lI14,0B 1300.00 12q9 9~ 1714,98 1400 O0 1399 9~ 1314.~8 ~500:00 ~499 9~ 14~4,~8 160o.00 1599 9~ 1514.~8 ~700 00 1699 9~ ~614.9B 1800~A0 ~7~9 97 1714.o7 lgo0.o0 18q9:95 1~14.q5 2oOO.O0 1999,94 l. q14.~ 0 34 2100 no 20q9 8R 2n14.R8 ] 6 220'0:n0 2199:5n 2114.58 5 46 230n.nO 2298."1~ 271~.78 ~ 30 2400.00 73q7,30 2317.~0 II 20 2500.00 9404 '15 240q.75 14 10 2600,00 ~501 0O 2506,09 ~6 56 2700.00 ?~5 Ul 2600,gl 20 2q 2800,00 ?.77~ ]4 2~93,34 ~4 7 2900,00 ~868 4? 278~,42 ~'1 7 85,00 FT 3000 O0 2956.3R 2a71.78 29 3B 3100~00 t042,:32 2957.32 ti 50 32 00,00 ]175,95 3040,g5 34 20 3]00.00 3207.45 3~22.45 ~6 39 3400 O0 32,6 27 370~ 97 q9 22 3600 00 3435 86 3350 a6 42 55 370~:~0 3508:7R 342~:7b 43 22 3aO0.O0 3§ali36 3496.36 43 37 3900.00 3653 42 3508.42 44 7 VERTTCAL DO~LEG RECTANGULAR COORDINATES HORIZ, DEPARTURE bECTION SEVERITY NORTH/SOUTH ERST/WEST DXST, AZIMUTH FEET BEG/lO0 FEET FEET FEET BEG MIN 0.00 0.00 0,00 N 0,00 O.OS 0.16 0,23 N 0,00 0,42 0 58 0,50 N 0,32 0,57 0:44 0,13 N 0,56 0.92 0,29 0,08 S 0,24 -0.14 0,15 O,Oq N 0,16 -0,43 O,Og 0,48 N 0,55 -n.73 0,16 0,86 N 0,95 -1.07 0,40 1,09 N 1,35 '1,36 0,09 0,84 N 1,58 '1.61 0,07 0,24 ~ 1,71 F 'l,8b 0,09 0,41 $ 1,80 E ~2,02 0,47 0,90 S 1,86 E 2.47 0,20 1,02 S 2,30 E -~,94 0,16 0,88 S 2,8t E '3.23 0,20 0.87 S 3,12 F '3,69 0 07 0,77 $ 3,61 E '4,34 0:07 0,41 S 4,36 F -4,g6 0,69 0,05 N 5,10 F -6,61 0,60 0,02 N 6,9~ K -~.~2 -6.17 0.32 11.42 27.35 49.03 75.63 107.62 ~45,48 188.78 236,76 287.34 t42,11 399.g7 526.26 593,50 661,64 796.06 2,01 2, 4 3.74 3 03 3 36 3 82 2 89 2 53 2 60 1 68 2 59 ! 96 0 67 0 20 0 73 0 1o 0 O0 N 0 0 E 23 N I 10 E 59 N 32 16 W 57 N 77 16 W 26 $ 71 27 ~ 9 N 60 10 c 3 N 49 2 28 N 47 58 ,.: 74 N 50 57 E 79 N 69_ 2 E 1,72 N 82 2 E 1 85 $ 7'/ 16 E 07 $ 64 13 g 51 $ 66 4 E 9'5 S 72 34 E 24 S 74 20 E 60 $ 77 57 E $ 84 37 E 10 N 89 24 E 95 N 84 54 E 0 94 N 3 53 N 9 03 N 17 26 64 N 30 78 N 45 70 N ~3.63 63,47 N 75,80 N 8 55 7:15 1,76 7,77 2t,92 41,8~ 67,07 98 07 134:66 ~76,25 8 60 N 83 44 E 7 97 N 63 42 E 9 20 N 11 0 E 18 82 N 24 21 W 34 50 N 39 26 W 55 70 N 48 40 W 81 16 N 55 4? 111 78 N 61 19. 148 86 N 64 45 W 19X:86 N 66 43 W 88 95 N 221 102 22 N 27 116 69 N 324 132 51 N 379 150 37 ~ 438 170 57 N 500 191 82 N 564 213 53 N 629 30 W 289 17 W 344 90 w 402 77 W 463 79 W 528 83 W 596 74 W 664 235,43 N b04,94 W 733 257,78 N 760,56 W 803 93 W, 239 10 N 68 9 W 92 h 60 21W 53 N 7012 W 34 N 70 46 W 82 N 71 5 W 98 N 71 ll W 51 N 71 14 W 96 N 71 16 W 73 N 7! ~7 W 06 N 71 16 W CnMPUTATION DATE: 5-JUN-R5 ARCR ALASKA, TNC. 3R-1 KI1pARIIK NORTH SI,OPE,ALASKA hATE.OF SURVEY: 06-MAY-B5 KELbY RUSHTNG ELEVATION: ENGIN~EP: HALFACRE/PEPPEL INTFRPULATED VALUF$ FnR EVEN 100 FEET OF MEASIIRED DEPTH 85,00 FT TRUE ~UR=SEA CnUR~F MEA$I1MFD VERTICAl, VERTICAL DEVIA?ION A~IMUTH DEPT~ DEPTH DEPTH DEG MTI~ bEG ~N VERTTCAL DUGLEG RFCTANGI]LAR CDORD]NATES HORIZ, DEPART[IRE SECTION SEVERITY N~RTiI/S~UTH EAST/WEST DIST, AZ[MI]TH FEET DEC/100 FEET FEET FEET DEG ~IN 4000.00 3725.30 ]640.30 43 59 4100.00 ]796.95 3711,95 44 21 4~0~.o0 ~86~,56 37B],~6 44 4 4300 O0 3940.8n 3R55 80 4] ]q 44un:nO 4012.7R 3q27:78 44 4KO~ O0 40R4.7~ ]q0qeTg 4] 45 4&O0~O0 4157.57 4n79.57 42 46 4700.~o 4211.06 4146.06 42 4] 48()o.~0 4304.55 4~1g.55 42 41 4900.00 4377.98 4~97,q8 42 48 N 77 16 W N 77 51W 1007.72 ~ 78 56 W 1076.~4 ~ 81 35 W 1146.13 ~! 82 2~ W 19~5 95 ~ ~3 26 w 135o,n3 ~ RI 38 W 1418,30 N R3 51 W 1485,70 5000 o0 4451.17 4366.17 a3 1~ 5100:00 4593.85 443R,R5 43 2R 5~0o.00 45~6 4] 45~1.43 43 ~1 5300.no 4669:04 4584.04 43 17 5400.00 4745 90 4656 qO 43 1R 5~00.00 4814:55 472~:55 4] ,~t 5600.n0 48~0.87 4RO1,R7 a] 44 570n,00 4958.94 4~7],q4 44 1 5800.n0 ~01U,74 4q45,74 44 1~ 5gO0.O0 5102,17 5017.17 44 ]7 g ~2 59 W 1553.39 N ~3 0 W 1621.72 ~ ~3 3~ W 1690.10 ~ 83 t7 W 1758.39 ~ R3 2] W 1926.50 N ~4 4 W 1R94.73 N R4 45 W 1963,22 w 85 3g W 2031,~4 ~, n6 2~ W 2100 56 N R6 4~ W 2169~57 6000.00 5173,33 50BR.~] 44 3<) 6100 no 524~.33 5~5~.~3 44 5n 6~On:O0 5315 01 5~30.nl 45 9 6~00.00 53~0:04 5~01.04 44 1~ 6400 O0 54~8 08 537~,08 4] 4R 6500"00 ~510:44 544K,44 43 29 6600:n0 5603.3~ 5Klfl 32 4.3 ~ 6700.00 5676,37 559~:~2 43 6 6800.00 ~749.47 56~4.42 ~2 bq 6900.00 5872.5~ 5737.~3 a3 6 ~I 87 17 W 2238,78 ~ 87 35 W 230~.04 ~' R7 51 W 2377.55 N ~7 0 W 2446 69 ~ 87 ~ w 2515:05 N ~b ] w 258].03 N fl5 52 w 2650,7] ~ R6 2R w 2718.~9 w P6 5~ w 2785,45 ~! 87 24 W 2~5~.~2 7000.00 58~5.51 5Rln.51 43 3 710o no 5966 b4 58B~.64 42 5~ 72on'no ~041:8R 5q56,~8 42 5q 7~00:00 6114· 9~ bO2q.e2 43 0 7400.00 61RB,26 blO~.2b 42 27 7~00.~0 626~ 45 6177.45 4! ~ 7fion.n0 6337~1~ 675~.16 41 3o 7690.n0 6404,~9 ~319,~9 41 ]9 ~ ~7 4] W 2919.~2 N ~'1 54 W 2Q86.81 N ~8 l& W 3053,62 ~.~ g8 27 W 31.20,58 ~ R8 4 W 3187.25 ~' ~8 13 W 3~53.03 ~ 88 1~ W 331~,23 M 88 12 W 3376.92 2,05 1,44 0 7O 1:41 0,81 0 5] 0,33 0,17 0.18 0,92 O,bO 0,40 0,78 0,'15 0,48 0 5] 0:5~ 0,54 0,43 0,47 0,52 0,53 1,89 0,56 4~ 0 ~6 0 4O 0 26 0,41 0,27 0,70 0,14 1 O6 1:47 0,00 0,00 279.87 N 8 .6.48 W 8?2 58 N 71 17 W 298 11 N 8"] 77 W 942 18 N 71 ]3 W 312 9R N W 1011 w 1080 338 59 N 1008,11 W 1149 348 27 N 1166,B2 W 1217 357,03 N 1234.83 W 1285 36b,17 N 1302,17 W 1352 372,7] W 1369,56 W i419 3RO,11 N 1437,03 W t486 60 N 71 58 W 35 N 72 22 W 13 N 77 51 W 68 N 73 27 w 41 N 73 39 N 74 20 W N 74 46 w 45 N 75 11 W 3R7,72 W 1504 74 W 1553,89 N 75 13 W 396,27 N 1572 90 w 1622,05 N 75 51 W 404 26 N 1641 2~ W ~6go,2R N 769 W 411 85 N 1709 56 W 1758,47 N 76 ~7 W 420 06 N 1777 56 W 18~6,5~ N 76 42 W 427 53 N 1845 86 W 1894,7] N 76 57 W 434 27 N 1914,60 W ~963,21 N 77 13 W 440 Oq N 1983,68 W 2031,91 N 77 ~9 W 444,81 448,99 N 21~2,9R W 2169,94 N 78' W 452 74 N 2~93,14 W 2239 455 98 N 2263,48 W 9308 95 N 78 ]6 W 458 78 461 54 465 45 469 13 N 9542 67 W ~585 59 N 79 12 W 474 30 478 87 482 84 486 2~ M 2815 40 W 2857,08 N 80 12 W 491,69 N ~9~1 B6 W ~99~,5] h BO-. W 493,95 N ]019 91 W )060,04 N BO 42 W 4. 7,85 N 3156 14 W 3195,17 N 81 2 W 500,06 502,1~ ~ ~289 59 W ]397,69 N 8! 19 W 503,99 C Flr. iP {J'T'A T I n~'l i.)A TF,:':3-JUN-R 5 PAGE 3 ~ATE UF SURVFY: 06-MA¥-85 KELLY RUSHTNG ELEVATION: ENGYNEER: HASFACRE/PEPPEL I~TFRPt)IoATED VAI, Uk;$ FOR ~VE~I 1000 FFET OF MFASURED ~)EPT TPU? SUn-SEA CnURSF' ME&StIRFD VF~RT]'('A[, VFjPTTCAL DEVTAT[n!'.I AF. IMIITH DEPTM DFPTH DLPTH DEG ~Ti'J DFG MTN 85.00 FT o.o0 O.On -BS.oO 0 n lnon O0 909.90 014,09 0 21 2000'00 19q9.94 lO14,g4 0 34 3o0o'~0 7956.]~ 2~7{,38 ~9 3R 4OOn~O 37~5.~0 3640.30 ~] bO 50On.a0 4451,~7 4366.~7 43 19 6000.00 ~173.33 50B~,33 44 3g 7000 nO 5805.51 5R10,51 43 3 7690~00 k4n4,3q 631~,~9 41 39 VER'i'TCAL D~}GLEG RECTANGUL~ Cn[)RDIN~T~$ HORIZ, DEPARTURE SMCTIa{.{ SEVERITY NORTH/~OUTH E~ST/WEST DIST, AZIMUTH FELT DEG/100 FEET FEET FEET DEG g 9 28 W -1.61 ~? 11 46 F -~.12 ~ 72 17 W ~6R.25 ~' ~2 5g W 155~.19 ~' R7 17 w 2?]8,78 ~' ~7 43 W 2glO,R2 0,07 2.05 0,92 0,47 §:4, O0 0,00 0,24 0 94 N 8,55 F 8 88 95 ~ 221,9] W 239 279 87 ~ 8~6,4R w 872 3~7 7~ ~ 1504,74 w 1553 452 74 N ~193,14 W ~239 4fl9 12 N ~893,70 W ~924 503 99 0,00 E 0 O0 N 0 0 E 72 N 8? 2 E 60 N 83 44 E 10 N 6~ 9 W 58 N 7! 17 W 89 N 75 33 w 39 g 78 2 89 N 80 10 N Bi 2 ARCO NORTH $I,[qPE. A~,A~KA CF),.i F'U'P A T I F1 N DATE; 5-JUN-85 PAGE DATE OF SURVEY: 06-MA¥-85 KELbY RUSHXNG EbEVATION: ENGTN~ER~ HALFACRE/PEPPEb i~TFRDOI.ATED VAIoUES FOR EVEN 100 FEET OF SUR-$E~ DEPTH 'tRUE SUB-SE~ COURSE ufASIIHFD YERTIrA]. VERTTC~L DEV?ATION 0.00 ().On -85.00 0 0 t~ 0 0 F 85.00 ~5.on ~,00 0 11 "19 46 F 18~.Oo 1~5.0~ lO~.O0 0 20 ~ 88 25 W 28~.00 2fib.On 20n,O0 0 14 S 0 I W ~85.OU 385.00 ~(.)n,0U 0 14 g ~3 52 ~ 48~.nl 4~5.0n ~)0.00 0 15 ~ K2 2~ ~ 58~.nl bSb.0n ~on,n0 0 1~ ~z 42 1~ F 68~.o1 6~5.0n &0o.O() 0 IR H 49 14 F 785.o! 785.Un 70n.no 0 1~ t~ 68 5~ ~ 885.nl 885.00 ROn.nO 0 19 $ 15 46 E 85,00 FT $~CTIDN SEVERITy NORTH/SOOTH E~$T/WEST DIST, AZXM[ITN FEET DE~/IO0 FEET FEET FEET' DEG ~IN ~.00 0,00 0,00 N 0,00 o.n5 0.19 0,1~ N 0,01 n.]4 0.73 0,52 N 0,23 0.59 0.45 O,lg N 0 56 0.~8 0,34 0,08 S 0:31 -0.10 0,22 0,05 N 0,11 -n.]9 0,0~ 0,41 g 0,49 -0,~8 0.16 0,~1 ~ 0,89 -1.02 0,26 1,09 N ~,3~ -1.t2 0,22 0,92 N 1.56 0 21 ~ 9 35 F -1.57 {) 22 g 7 24 ~ -1.81 0 14 S 19 ~ W -~,98 0 1~ ~ R3 36 E -2.39 0 14 H R4 33 F -2,R8 0 ~ ~ ~ 2~ F -3.20 0 25 ~' 72 46 E -],59 0 27 N 58 ]g ~ -4,26 0 ]6 ~: 61 ~6 ~ -4.83 I lg ~ 7~ 45.F -6.~9 108~.Ol IOR5.00 lnun.no 1185.~2 llRb. OO llOn,nO 128~.02 12~5,00 l?on.o(~ 1385.02 13RS,On 130o.no 1485,o2 lqA5.OO 14on,oo 1585.n2 15~5.0n 15~)n.no 178~,o3 O0 1700.00 1785'00 1800 O0 1885.04 ~Sb. . 1o8K,06 ~9P500 lqOn.~(,~ 0 3~ 2085.10 ~085:00 2oon. Oo 2 3q 21.8~o35 ~1n5°oo 2100,00 5 2n 2786.n7 72~5 un 2?on.n() ~ 2387.46 73~5~u0 23on. Ou 10 54 24~.~.% 7485, O0 240n.00 ~4 2699.14 26q500 2~O0.nO ?0 27 2~07.]3 9795~00 2700.0U 24 22 2q~.67 ~8P5.()0 2~un,no 77 t7 34 1~ W -A.73 4'1 16 W -0.92 KU 45 W 9.58 K8 49 W 25.03 &5 21 W 46.61 73 35 W 73'77 70 4 W 107.32 73 50 W ~48.53 73 34 W ~97.~4 3033.05 99~5.00 2~OO.00 30 21 3150 68 30R5.0n 3000.00 33 14 3277:13 3185 00 ]10n,00 3530 84 3385,00 33on,OU 42 17 3667:]3 3485,00 340~.00 43 3805~03 35~5,00 3~0o,n() 43 38 3944,00 3hR5,00 3600,00 4~ 4~8~.?~ 37R5 00 370~,00 44 21 4727.~6 3885~00 3800,00 43 54 N 74 5~ w 252 77 ~I 74 41 W 314:64 N 73 58 W ~,' 72 14 W 460.~! ~' 71 4n W 546,84 ~ 71 3n W 63~,32 ~ 71 1~ W 733.53 ~' 71 22 W 82g.55 N 7D 53 W g26,23 N 7~ 4 W 1023,59 0 00 N 0 0 E 0 18 N 2 52 W 0 57 N 23 52 W 0 59 N 71 42 W 032 $75 7 W 0 12 N 66 46' 0 64 N 50 t 20 N 47 44 e~ 69 N 50 ~9 E 1.81 N 59 31 E 0,06 0,01 0,35 0,2~ 0 27 0 07 0 30 0 17 0 46 0 58 O, 3] 0,31 0,84 1,0] O' O,UI 0,47 0,02 0,56 1,69 F 1,7q E 1,84 E 2 21E 2 75 E 3 08 ~ 3 50 ~ 4 26 F 4,96 ~ 6,58 E 1,73 ~ 78 53 E 1,82 S 80 9 E 2:o s E 44 $ 64 58 E 89 $ 72 10 E 3,59 $ 76 59 E 4,28 S 83 39 E 4,96 S'89 43 E 6,61 N 85 8 E 2 76 3!29 3 ~6 2 7~ 3 69 3 22 3 8O 3 49 2,44 0,8~ N 2 V~ N H 07 N 15 88 N 25 40 N 35 75 N 45 19 N 53 56 N 64 78 8,40 E 8,53 N 84 23 E 7,59 E 8,13 N 6a 56 E 2,81 E 8,55 N lq 12 E 6 1~ W 17 04 N21 13 19 82 W 32 22 N 37 57 W 39 59 W 53 34 N 47 54 ~ 65 28 W 79 39 N 55 07 78 W 111 4o N 61 17" . 32 N 137 58 W 151 88 14 64 56 W 25 ~ X84 46 W 200 37 N b7 0 W 90 2' ,77 2,48 2,56 35 ]9 83 58 75 93 30 N 237 8~ W 255 52 N 68 35 W 109 38 N 297 67 W 317 13 IS 69 49 W 127 92 N 364 150 04 N 437 177 07 N 520 206 41 N bO8 236 53 N 698 267 61 N 789 295 57 N 882 3]6,28 N 977 04 W 385 86 N 70 38 W 77 W 462 77 a 71 4 W 35 w 549 65 I~ 71 12 W 48 W 642 54 N 71 ~5 W 22 W 737 20 N 71 17 W 59 w 833 71 N 71 16 W 35 w 930 54 N 71 28 W 50 w 3027 39 N 72 4 W Cn~PU?ATInN OAT~': 5-JUN-R5 5 ARCa ~bASKA~ TI~P. 3~-1 K~IP~RIIK NORTh ,5T,OPlf, ~ ALASKA PAGE ~ATE Ur SURVEYI 06-MA¥-85 KELLY RLISHTN~ EbEVATIONj ENGTN~ER: HALFACRE/PEPPEL 85.00 FT LNTFRPUT,ATEh VA[,UFb FOR EVEN 100 P£FT UP SUR-SEA DEPTH TRUF SUn-SEA COUPSW MEA$11RFD VFRTICAI. VgPTTCAL DFVTATIO~ AXI~LJTH DEPTH DEPTtt DEPTH DEG f4TN DF(; HTN VER'rTCAb DOGLEG RFCTANGUSAN COORDINATES HORIZ. DEPARTIlRE SECTInN SEVERITY NORTH/$OUTIt EAST/WEST DIST. AZTM{ITH FFET DEG/IOO FEET FEET FEET DEG NIN 4361.30 39n5.00 300n.00 44 4K00.78 40n5.0n 4000.00 43 45 4637.~3 alPS.On 4100.00 42 ,%1 477~ 4! 42R5.0¢~ g~O0.O0 42 40 5046.48 5184.94 45R5.00 4KO0.O0 43 5321 ~2 5459:?3 47~5.0~ 47{;0.00 43 26 5597.~! 4885.00 ~SOO.OO 43 44 5736.77 49~5.Uo 4ooo.nu 44 5 5R75.qO 5095.00 5~0o.00 44 31 b016.39 51R5.0n 5100.00 44 49 6157.49 K2~5.0~ 5?un.nO a5 5 6~9R K5 K3R5.0O 5~00.00 a4 14 6437~99 54R5.00 540~.00 43 44 6574 ~9 55~5.00 550n OU 43 ~n 6711'q0 56R5.00 5&O0:O0 a3 6 6R4R~63 57R5 O0 57on.no 43 ~ 6q85.~0 5885~00 5R00.00 4] ~ 7122 37 59R5 O~ 5gOn. O0 4~ 57 7530.18 62nS.on b2on.no al 3O 7664.~4 ~385.U0 otO~.oO al 3° 7690.00 64~4.39 o]19.39 41 ~q ~1 PO ~3 w 111q.27 ~: R2 2~ W 1215.45 ~' n3 ~ w 130R.68 f; P3 51 W 149~.16 ~ 83 6 W 1773.33 ~ ~4 44 W 1g61.44 ~ R6 1W 2056.76 ~ 86 3n W 2159.ql ~' R'; 14 W 275n.ll ~ 87 44 w 2347.g7 ~. R7 2 W 2445.70 ~: P7 1! W 2540.45 W ~5 42 W 2633 75 ~ gb 3~ W 272~2~ ~ ~'1 q W 2Rl~.ll N 87 40 W 2910.~6 ~ g'l 57 W 3n01.79 k B~ 26 w 3n9~.22 ~' R8 % W 3184 31 N R~ 12 W 3~72:70 N ~8 19 W 3359.g9 ~ ~8 17 W 3376.Q2 2.56 0.53 0.51 0.14 0.27 0,51 0.54 0,82 0,54 0.76 0.45 0 65 0!32 0 86 0,o3 0.31 0 51 0:35 0 42 0i53 1 04 O.O0 0.00 0,00 334,55 N 1071,47 W 1122 49 N 72 39 W , W 1217 88 N 73 22 W 360'77. N 1351 64 W 140 1492 88 N 75 i3 W 348 20 N 1167 Ol 14 N 1259:96 W 1310 370 380 80 M 1443 50 W 391 72 N 1536 37 W 1585 403 05 N 1630 44 W 1679 413 64 494 57 M 1817 94 W 1866 434 11 N 1912 82 W ]961 42 N 74 2 W 56 N 74 39 W 52 N 75 41 ~ 51 N 76 6 39 N 76 30', 86 N 76 51 W 46 N 77 12 W 441.92 ~ 2008 83 W 2056.87 N 77 35 W 448,01 N 2106 11 W 2153,23 N 77 59 W 453.30 N 2204 64 W 2250,76 N 78 22 W 457.6~ N ~304 08 W 2349.09 N 78 45 W 461.49 N ~403 48 W ~447 3q N 79 7 W 46 71 ~ 2499 52 W 2542 72 N 79 25 ~~i 47 05 ~ ~593 81 W 7636 60 N 79 39 W 479.37 ~ 76~7 25 W 2729 67 Iq 79 53 W 488;7~ N }873 88 w ~9~5 14 N 80 20 W 402 25 N 2967,10 W 3007 66 N 80 34 W ~q5 1l N ]060,28 W 3100 07 N 80 48 W 407 75 N 3153,16 W 3192 20 N 81 I W 500 68 N 3243 20 W 3281 b2 N 81 13 W 503 45 ~' 3332:14 W 3369 96 N 81 24 W 503 99 N 3349,39 W 3387 10 N 81 26 W ARC~ Ab~SKA~ NORTH bASF ~,OWER ,q. AWO P ~"1' D T 17'].' h b DEPTH COHPdTATImN DA'£Fi: 5-JUN-R5 PAGE 6 DATE.OF SURVEY: 06-MAY-85 KELLY BUSHTNG ELEVATION: 85,00 FT ENGINEER: HAbFACRE/PEPPEb 1NTF. RPOI.,ATLD 'WA[,uF$ FOR CHO,KEH HORIZONS SURFACE LOCATION AT ORIGIN: 77b' FSI.,, 852' FEI,, SEC 16, T12N, R9E, UM TYD RECTANGULARCO ORDINATES FRoM KB SUB-SE~ NORTH/SOUTH EA6T/WEST 7162,00 6014.n4 5929,04 49] 16 N 725q.. On bn84 .04 5999,94 495',11 N 7379,,)0 617~.79 60,7,7g 497,~8 N 7557,00 b~05,04 ~220,04 50],2~ N 7589.,)0 6~2".q4 624].94 50'.gO N 7bO0,On 0404.39 6319,30 503,99 N 2994 Ob W 3060 23 w 3141 95 W 3~6! 02 ~ 3282 ~8 k 3349 ~9 W ARCr~ ~bASKA. NORTH ST, OPE,AI,ARi~A CD:~IPOTATInN DATE: 5-JUN-B5 PAGE '7 DATE .OF SURVEY: 06-MA~-B5 KELLY BUSHIN~ ~L~VATION: 85.00 FT ENGINEER: HALFACRE/PEPPEL 7162.00 7259.un 7379. On 7657.00 75R9.0o SURFACE LOCATION AT []RIGIN-- 776' FSL, 852' FEI,, SEC 16 T12N ~9E, [IM TVD RECTANGU[.AR C60RDIN~T~S FRO. KB SUB-SEA NORTH/SOU~H EAST/WEST 6nl4.04 6n84.q4 o177..79 6~305.o4 6.q2R.q4 6404.39 5929 U4 59g9 94 60~7 7~ 6220 04 6243 94 6319.]9 49),16 N 495,11N 497,38 N 501,~3 N 501,90 N 503,99 N 2994 06 W 3060 23 W 314t 95 w 3282 :~28 ~ w,, 3349 39 W FINAL WELL hOC&TToN aT I'PUE SUB-SEA MFASURED VERTICAl, VERTTCR[~ DE:P'£H i) F, PTIt BEPTH 7ba,J. O0 t, 4,34.39 6319, ]O UORTZONTAI, DEP.ARTtJRE DISTANCE AZIMUTH FE~T DEG MTN j~87.1,0 N 81 26 W SCHLUMBERGER O I RECT I ONiqL SURVEY COMPANY ARCO ALASKA INC NELL 38- 1 FIELD KUPARUK COUNTRY USA RUN ONE OATE LOOOEO OS-MAY-SS REFERENCE 0000704S4 WELL NAME: 3B- 1 SURFACE LOCATION: 776' FSL, 852' FEL, S16, T12N, R9E, UM VERTICAL BROJECT ION 6000 283. PROJECTION ON VERTICAL PLANE 28B. - 103. SCALEO IN VERTICAL OEPTH$ HORIZ SCALE = l/lO00 IN/FT WELL NAME: 3B- 1 SURFACE LOCATION: NO~TH 4000 776' FSL, 852' FEL, S16, T12N, R9E, UM HORIZONTAL PROJECTION SCALE : 1/I000 IN/FY 9000 ~000 I000 -I000 -2000 -9000 $OU~H -4000 ~T-~'"T'T-'? ..... ?"?"?"t'"~ ..... 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"' ' ' ' ~' .......................... ~ ........ : ..... ~' ~"' ..~ .... i ........ ? ..... . ................................................................... ~ ........... :'''~ ............ ~'mm~''') .......... :' ~' ' .............. ========================:: ================================================================================================================ :"::;':'-':t'":' :':::' :"i":':':': t':: .... :': i'::'' I':'::: i":':': :' )'"":':: i '::: I -SO00 -4000 -9000 -2000 - 1000 0 1000 2000 3000 EAST Suggested form to be inserted in each "Active" Well folder to check for timely compliance with our regulations. 'OP~.RATOR, WEL~AM~. AND 'NUMBER Reports and Materials to be received by: ~--- · D~te Required Date Received Remarks · Completion Report Mud Log Core Description ., n Survey Drill Stem Test Reports Production Test Reports Log Run ~ _Digitized Data ARCO Alaska, Inc. Post Office Bb~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 :;17. TURN TO' AI:::CO AL.A£1~6, INC., A'T'TN' RIZCOI'-.~I)5' C~L..li.":l:~l( ~ 'i" 0 -- t t I 51:3 F', O, I!l.r.)x I 0036,.'.) ,~'-it~.CI./OF;~,qG.[:', AJ( 995'1 0 DATE:'. TF,:ANS,'MI'F'I"AI_ N0'5t 70 :RAN£HITTEI) HI.'T.F::F;:W];TH AF:I!.". THE F'OI...I._OW];NG :~17. C1:7. IF"1" AND R'ETLIRN OI',~F.'.'E ,.'5' }F;'EEN HOLE LIS TAPE,? F'I...U,S' -'CI--ILI.IHP. EI;~GEI~ ( ONL-': COI::'Y ]; 'I" I": H ,.? , I::'I...E?'~,5'E ACK i",/OI,'JI..E:I)GIE ]]GNI:.D COPY OF THIL," TRANSH];TTAI_, I... ]; S T ]; N G CI I-- I:.,~ L, I"1 ) i (i~ 3 0 ,'3_ - 3 O.- El 55 R U N :,": t '":'" "- ,,. · ..).._'10 0-10~115 5 RE- ,9U'-8 03'-~c.q'"1:'15,'- F:UN .... f 29~'~ 3 '" - "~' '"'--' ~' -;.,~. 5-696 5 I'~I:-F ,,- ,).[.l-"9u'/ O,l-O4-.(.:lq RI.IN .~,"t i36"'7 5 ~i05~'5,."5 ."-.'-'"" '~'~-,' ..... c, , - REF.,,. ?0.._, , -~t,J.- t ,_q," 01 -")8-I:;..>,~.. RUN .,,. ..... I 31.. I 6 ,5-'7038 ,5 REF:,":"?O~'? ~}7.i~-"t t,,,'_~-04-1 3-',51':~ RI.IN :,":1 S.3"~lil 5'-7703, O REEF' .,-7030~ ~' " · ^;. n '1 {B-J 5/ 03 ,-.. ?'-'0.> RLIN ~",:t 3992, 0-8463, 0 RI'-.'.F:~,:70251 _'~.B - 1 6 04-06-85 RUN :,~:t -'"' '') ooc, i . 5-"?B46.0 I:iEF~:'?'0276 · Y-'/o CEIF'T C U R F,' ]: E R I ..... ;:.) I"I N,S' T C] N !17. V I':..' 0 N I"i 0 [.;: 'r & M i'l,'.-i'l( "!..I::F;:I( ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 15, 1985 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Encl osed are the April monthly reports for the following wells' 1Q-1 2U-10 2V-12 3B-16 9-28 1Q-2 2U-11 2V-13 3-16 (workover) 17-14 1Q-16 2U-12 3B-1 4-32 L1-1 1R-5 2V-10 3B-2 9-16 (workover) L~-9 2U-9 2V-11 3B-3 9-27 L2-28 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU6/LI06 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK, __..,.r--AND GAS CONSERVATION CUl~tlSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS !1. Drilling well ~( X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-56 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21318 776' 4. Location of Well atsurface FSL, 852' FEL, Sec.16, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 85' RKB 6. Lease Designation and Serial No. ADL 256:3:3 ALK 2566 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3B-1 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. April ,19 85 1 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1645 hrs, 4/8/85. Drld 12-1/4" hole to :3:379'. Ran, cmt, & tstd 9-5/8" csg. Drld 8-1/2" hole to 7680'. Ran OHL. Drld to 7690'TD as of 4/14/85. Ran, cmtd, & tstd 7" csg. PBTD = 7589'. ND BOP. NU tree. Secured well & RR @ 2400 hrs, 4/15/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 110'. Cmtd w/278 sx PF. 9-5/8", 36.0#/ft, J-55, BTC csg w/FS ~ :3:357'. Cmtd w/950 sx AS III + :300 sxs Class "G" + 100 sx AS I (top job). 7" 26.0#/ft, J-55, BTC csg w/FS @ 7677'. Cmtd w/:375 sx Class "G" cmt. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/SFL/GR/SP f/7676' FDC/CNL f/7674' - 6950' Cal f/7674' - 6950' 3361' 16. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED (~ ~P/~/)(J ~~ TITLE Assoc__~a__~e__ E_ngi ne__e[ DATE ~"/--~-~ NOTE -Repgt on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 JMM2/MR07 R~.v. 7-1 Submit in duplicate ARCO Alaska, Inc. Post Office B~,,, 100360 Anchora§e, Alaska 99510-0360 Telephone 907 276 1215 llay 3, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plats - 3B Pad Wells 1-4, 13-16,~" Dear Elaine' Enclosed are as-built location plats for the subject wells. you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU6/LI01 Enclosures If AliCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany WELL 1 Y:5,ggl,896.45 Lat. ?0°25' 20. 5210'' I X= 518,178.72 Long. 149051'07.67:5'' O-G. Elev. 49.6 Pad Elev. 5~.6 776' FSL 852' ~L ~,[ IELL 2 Y=5,~1,956.26 Lat. 70°25'21.1094" X= 518~i72.79 Long. 149°51'0~84~'' ~ 836' FSL 858' FEL o5 WELL ~ Y=5,992,015.79 La/ 70°23'~1.695t'' ' 3e o6 ~ X= 518,167.27 Long 149°51'08.000''. 07 I~ O.G. Elev 49.2 Pad Elev 54.6 .. ~e~ · o8~ 896' FSL 86~' FEL WELL 4 Y=~992,075.65 Lat. 70°25'22.2840'' [~ X= 518,16,.64 Lon,.,49°5,'08.,61'' 955' FSL e68' FEL , WELL ~3 Y=5,991, 169.7~ Let. 70° 2~ 13.3712" ,~ ]~ X: 518,~47.~0 Long. I~9° 5,'05.6~" O.G. E[ev. ¢8.5 ~d Elev. ~.4 49' FSL 786' FEL o9 ~ · olo WELL t4 Y=5,991,229.62 Lat. 70° 23'13.9~7" t5 · ott X= 518,242~16 Long. 149°51' 05.865" t4e 0t2 QG. Elev. 49.0 Pad Elev. 55.4 ~3 · 16~t5 t09' FSL 792' FEL ~ 2~22 WELL ~5 Y 5.~,,2e9.~ L~t. 70°2~',4. S~,'' ~~l X= 518,256.44 Long. 149°51'06.0~'' O.G ELev. 49;0 ~ Elev. 55.7 ~ 6 9' FSL 797' F E L WELL ~6 Y=5,9~,~.~7 Lat. 70025. X= 5 I 8,2~0.79 L~g. 149° 51'~. 188'' OG. Elev. 49.0 Ped Elev 55.4 SCALE N TS 228' FSL ~2' FEL LOCATED IN PROTRACTED SECTION 16, TOWNSHIP 12 N., ~- OF A~ RANGE 9 E., UMIAT MERIDIAN. ~-j: ~-~ ::r C~ ~ ~ / ~'~ ~":~ ,~ ~%~e,,.e ~ ~% ~-, ~.-~ ~: ~ .~ ~...: ~ COORDINATES ARE A.S.P, ZONE 4. SECTION LINE ~{~/ .~ ~-~ VERTI~L POSITION ~R LHD S ALCAP T~ S 3B-fl~3B-12. ~ ~ ' ~ I HEREBY CERTIFY ~HA* I AM PROPERLY REGISTERED AND Cp.(ii LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ~ N~~ ~ ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE ~~. ~ ~ UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ~ ARE CORRECT AS OF MARCH 3,1~5 FOR WELLS 1-4&13-16. ~s ~, ARCO Alesko, Inc. ~ q~ r. ~~ Kuperuk Project North Slope Drilling CONDUCTOR AS-BUILT LOCATIONS 20 ~.~ Date:M~ch1~,1985 Scale: AS SHOWN / ~--/ Drawn By' D~.~ Dwg. No. NSK 9.~.302d2 i MEMORANDUM State of Alaska TO: THRU: FROM: ALASIZ~-~ OiL AND GAS CONSERVATION COI~R4ISSION C. V..~C~'~ ~erton Chai=h~/ . / Lonnie C. Smith ~'¢'- '~' Con~is s ioner TELEPHONE NO: Bobby Fosr~r~'~/;~:~ ~ Petroleum Inspector DATE: April 12, 1985 FILE NO: D.BDF 28 SUBJECT: Witness BOPE Test on ARCO' s 3B-i, Sec. 16, T12N,R9E,U!;~, Permit No. 85-25. Wednesday, April 10, 1985: The BOPE test began at 3:00pm and was ~-6~-~e~--it 4:30 pm. As the attached BOPE test report shows, there was one failure. This is to be repaired and the AOGCC office notified. Attachment I was notified this day, April ti, 1985, that the dart valve had been repaired and teste. O2-O0~AfP, ev ~0,,79,~ o~c #4 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report ~Iud Systems Trip Tank Pit Gauge Flow Monitor Cas Detectors B~P~E~Stack '- Annular PreventeK.,-,~ ,/ Pipe Rams Blind Rams Choke Line Valves / H.C.R. Valve Kill Line Valves Check Valve - Visual Audio , ~ ,'Tes~t,' Pre,:ssure Test Results: Failures / Repair or Replacement of failed equipment ~o be made Within ~ days and Inspector/ Commission office notified. · x/,/a. ..... " Full Charge Pressure ~~O psig Pressure After' Closure /~0 ~ psig Pump incr. clos. pres. 200 psi~ --/ min, sec. Full Charge Pressure Attained: ~ min~% sec. · Controls: Master Remote ~ Blinds switch coverCf~ Kelly and Floor Safety, Valves Test' Pressure Lower Kelly / Test Pressure , ~ Ball Type / Test Pressure ~,~,~ Inside BOP ! Test Pressure ~~ Choke Manifold ~~ Test Pressure No. Valves. No. flanges Adjustable Chokes / Hydrauically operated choke / ' , Test Time /~-Z?hrs ..... Distribution · orig. - AO&GCC cc - Operator cc - Supervisor March 28, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3B-! ARCO Alaska, Inc. Permit No. 85-56 Sur. Loc. 776'FSL, 852'FEL, Sec. 16, T!2N, R9E, b~4. Btmhole Loc. ].523'FSL, 1191'~, Sec. 16, T12N, R9E, IFM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by ~h~ Habitat Coordinator's Office Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Admin~strative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conse~ation. .'._~. Jeffrey B. Wewln Kupsruk River Unit 3B-! -2- March 28, 1985 To aid us in scheduling field work~ please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. I~ere a diverter system is required, o!ease also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advanCe notification so that we may have a witness present. Ve~_t~ruly yours, C. V. c~a~tertOn Chai~an of Alaska Oil and Gas Conservation Co~ission BY OP~DER OF THE CO1-R,{ISS ION be Enc].osure CC: Department of Fish & Game, Habitat Section w/o enci. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office b,.. ,00360 A~',choi'age, Alaska 99510-0360 'Felept'lone 907 276 1215 !'-larch 19, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 3B-1 Dear Mr. Chatterton' Enclosed are' o We estimate spudding this well on April questions, please call me at 263-4970. Sincerely, Area Dril ling Engineer JBK/TEM/tw PD/L59 Attachments An application for Permit to Drill Kuparuk 3B-1, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat Diagram and description of the surface hole diverter system Diagram and description of the BOP equipment 8, 1985. If you have any RECEIVED Alaska 0il& Gas Cons. Oommissiorl Anchorage ARCO /,,la.';ka, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~,,L AND GAS CONSERVATION CO,~,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL []× REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC ~ SINGLE ZONE [] MULTIPLE ZON E)t~ 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360~ Anchorage~ Alaska 99510 4. Location of well at surface 776' FSL~ 852' FEL, Sec.16, T12N, RgE, UN (Approx¢!)i, -,,,~.:, ~ At top of proposed producing interval 1437' FSL, 1566' FWL, Sec.16, T12N, RgE, UH At total depth 1523' FSL, 1191' FWL, Sec.16, T12N, RgE, UN 5. Elevation in feet (indicate KB, DF etc.) / 6. Lease designation and serial no. RKB 85', PAD 55' ~ ADL 25633 ALK 2566 9. Unit or lease name Kuparuk River Unit 10. Well number l~'.~ield and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance ar~ direction from nearest town 30 mi. NW of Deadhorse miles 16. Proposed depth (I~D-& -I:~D) 7622' ND, 6420' TVD fe~t 14. Distance to nearest property or lease line 776' ~ surface feet 17. Number of acres in lease 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 1969 feet. MAXIMUM HOLE ANGLE #2 oI (see 20 AAC 25.035 (c) (2) Amount $500,000 15. Distance to nearest drilling or completed 3B-16well 550' ~ surface feet 18. Approximate spud date 04/08/85 2828 psig@ 80°F Surface 3236 psig@ ¢,27! ft. TD (TVD) ZI Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 62.5# H-40 Weld 80' 29' I 29' 109 109' ± 200 cf 12-1/4"! 9-5/8" 36.0# J-55 BTC 3332' 29' 29' 3361'1 3241' 920 sx AS III & HF-ERW * I 300 sx Class G 8-1/2" 7" 26.0# J-55 BTC 7594' 28' II 28' 7622'1 6420' 260 sx Class G blend I HF-ERW I I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7622' ND TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing w~11 be set through the West Sak sands at approximately 3361~ ND(32~1~ TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It w~11 be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure ~s 2828 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, ~ncluding temperature effects. Selected intervals will be logged. The well will be completed by the workover rig with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby certi/~that the foregoing is true and correct to the best of my knowledge ....SIGNEDf__///~~d~(~_.~~¢~ TITLE Area [)tilling Fngineer The spac~'-yow f~ifC'(T_./6m/~ission use CONDITIONS OF APPROVAL Samples required Mud Icg required . Permit number Approval date Form 10-401 ( ~'"~D~'PD5 9 Rev. 7-1-80 Dir,,~¢ctional Survey required ES E]NO APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE March 2R, ] 985 by order of the Commission Submit in triplicate PERMIT TO DRILL 3B-1 installed and tested upon completion of the job. 3B-1 will be 550' away from 3B-16 at the surface. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 6044'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the workover rig has moved off location, this well will be fracture stimulated. ........, HOR I ZON_TAL PROJE CT I oN..i I : ' SC LE 1 IN. l" 1000 FEET ..~ ........ 4 ........~ .... · ' ' ' ..... ~...~._=~..~ ...... , ........... : ~- - ~, ......... ( --, ,_-, , . ............... . ..... ; i i PAD 3B.:WELL~ldO~ 1' ' ,PROPOSED ' ,,,. ,'I'i, , i_ '.,' FUPARUK;FJ£LD.. NORTH I SLOPE. ^LA~KA~ ..~i ' ~ASTMAN WHIPSTOCK~ INC. , '' j wEST~( AST ' · ' ~ .......... . , , ) · . , ~ .,, ' ~oo9 , ,~ ~ooo p~ooo, - ___"' sooo ~ooo ~ooo ~ ] . . .. o · ,, __ . - : . . . ~_: ...... :, ..... ! - . . , ~ · , 0 ........ _._~UF~AC:E · _ ., : -. , ',_ . ' . . ......... 1000 _ ~ ~ -, .... .--:- 4-'. 2000 _, 3 TOP UONU SNDS 'TVD=2036 THD=2036 '~ ~ ~- - i ...... .... : ....... , ........ BUILD 3 DEG ~R I~FT TOP-~ SAK SNDS TVD=2726 -TMD=.274.7; _3000._ 33 ~ K~I 2 .... TVD=-30~'IL'LT, -- 3~' Eoc (csG P.T)-.--- I ' -, -; -'F ........ 5000__ _ ~HD__-585~-.DEP~21-45 .... ...... !- , _ . , ! ........ : ............ ~ ._ - - L.. _ ............. ! '- ............. ! ..... . .................... : . .£ .~_1_! . - _; ............................ _ · . ........... ' ~ " ' -- .... : .... ;'-4 - -- i- ....... :- --~ -- ' '_..6000_, ' .... UPPR! SNDS TVD=5989 Tt'ID=7044 DEP=2938-- : . _.. , ....... · ....... >, _',_,T'A~RGET"-CNTR._' ' TVD-=6109 'TMD=7205--DEPA'r3045 ~~ TOP LO~R SNDS TVD=6142 TI'ID=7249 DEP=3071 . ; . i.--: ................... ~ .... _-BASE~ KUP SNDS TVD=6271 TtID=7422. DEP=31! ...... _ ___ j'__ ...---T .... TD-_--~(LO~ PT) ..... TVD=6420-Tl'ID=7622-"DEP=332~ , : ', -.- ..: ..... ~ .: ..... L ........... ' - . .... 7000 . . _ ............ 2000 3000 '-';'- 4000 ..... ~ ~"':~'~;~-~'~-'~-'~' ..... '~. .............. : ..... 0 000 --_ ........................... VERT~CAL:.SECT-[ON ...... ~ .... : ..... ~ .....; '._L; ..... ' .._. ~: .......... . .... . .. - ........... -: ...... ~ ........ :-Al~,.Oi~:& Gas Cons, . .. F. , _ .-. : _ , ..... : _ . - . . ; ....... ; .... ~ . i--J 5 4 2 tI DI A~,AM #1 ~ '-"0 PSI RS~A BOP STACK z t~' - 3ooo Psi c~s~ ~ 4. 13-5/8' - 5(I)0 PSI PIPE RA~ 5. I~-~/0' - .5000 P~! BI,ILLIN3 SPODL )Z/O-~ A~ KILL LIhES 7. 1~--5/8". - ~ PSI AhN.L~ ACC~ATOR CAPACITY TEST I. O-E~ AhD FILL ~TC~ I~~IR TO LEVEL WITH ~IC FLU]D. 2. ASSU;~ THAT ACO. I,4JLATCR ~'I$ 3000 P~I WITH 1500 PSI ~TEEAM CF TIE 3. ~R'VE TIbF_~ TH~N CLOSE ALL L~TS SI~LLTA~OJE~_Y AhD REC~ 'r~ T]~ AhD PEESS~ RE~,ININ~ AFTER 4. ~~ ~ ~ ~T, T~ ~~ L~ LI~T ,1 13-5/8' BOP STACK TEST FILL BOP 5'Tw~::K AhD ~ ~qN3F~ WITH ARCTIC DIESEL. O-ECK Tt4AT ALL LOCK EX~ SCREt~ IN ~ELLI.'~ ARE FLLLY RETRACTED. SEAT TEST PLUG IN ~L~F_AD WITH RLI~IN~ JT AkD RLt,J IN LOC~ SC~E~ CLOSE ~ Pf~-VENTER AhD ~ KILL A~ ~ LIhE VALVES ADJACENT TO BCP STACK. ALL OTI-k-E 4. PI:;E:SSLI~ LIP 'FO 250 PSI AN3 HOLD FOR IO MIN. IN- C~ F~SE~I~ TO 3000 PSI AN;) HOLD FOR I0 14IN. BLEED F~~ TO 0 PSI. 5. CPEN A~A~ P~NTE~ Ah~ )¢A~ KILL A~ O40<E LIhE VALVES, CLOSE TOP PIPE P~ AND HCR VALVES ON KILL A~ C~ LIbEl. 6, TEST TO 25O PSI AhD ~X)O PSI AS IN STEP 4. ?. o~rrI~ TESTIN~ ALL VALVES, LIhES, AND CHaKES ~TH A 25O PSI LC~ A~> ~000 PSI HIGH. TEST AS IN STEP 4. DC)bDT PF,~. h-'SLI~ TEST ANY ~ Tt-CkT IS hOT A FLLL O..OSZh~ POSITIVE .~ 0-0~. O,4.Y 8. CFF_N TOP PIPE RA~S Ah,D CLOS~ ~o'rrc~ P]PE P,A~. 'rEST BOTTC~ P[P~ ~ TO 25O PSI AhD 3000 PSI. 9. O:'EN BOTTOM P]I~ P, AJv~ BACK oyr ~J,,~N~ Jr-A~ 1(3. O._OSE BLIhD RAMS AAD TEST TO 250 PSI AhD PSI. MANIFCLD AN3 LIhES ~ FLLL OF ~EZING FLUID. SET ALL VALVi-r.S IN DRILLING POSITICI% I~ 'lEST s'rAhI~IPE VALVE.~ KELLY, KELLY C(X:X~ D~ILL PIPE SAFETY VALVE,, AN~ INSID~ BO:) TO 250 PSI ;~300 PSI, i;~ TEST II~F~TION ON 1~.~ ~ER TEST F~k~ SIGN, AhD S~hD TO DRILLING SLPERVISC~. ~EEKLY THB~AFTER FI.NCTICNALLY ~TE ~ DAILY. 5 ! 008400 ~ I~v .7 6 7. 20"~bel 1 n~pple. Surface Diverter $~stem 16'-2000 psi Tankco starting head. Tankcc quick connect assy. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/lO' s~de outlets. 10' ball valves~ hydnaultcally actueted~ w/l~* lines to reserve pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annular preventen. Ha~ntenance & OD,ration Upon initial i-nstallatto~' c~ose annular preventer and verify ~hat ~all valves have opened proper~y. Close annular preventer and b~ow air through dtverter lines every 12 hours. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary~ manually overr~de and close ball valve to upwind d~verter line,. Do not shut in well under a~7 circumstances, Conductor I ECEIVED 2 6 1985 Alaska Oil & Gas Cons. Commission Anchorage CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Company Lease & Well No. YES NO . . REMARKS (1) Fee /~ ~-2~-~ 1. Is the permit fee attached ....................... , .................. ,~d~'__ (2) Loc ~/r~) K .~- 7-/~-gor' (2 thru 8) (8) (3) ddmin ~~ S-Z&-o~ 9. (9 thru 12) . 10. '(10 and 12) -- 12. 2. Is well to be located in a defined pool ............................. ~/~ 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. /~ Is a conservation order needed ...................................... /~'. X,4OF Is administrative approval needed ................................... ._/r/~_ Is the lease number appropriate ..................................... ~ ' (13 thru (5) BO?'E (22 ) (6) Add: 13. 14. 15. 16. 17. 18. 19. 20. 21. ! 23. 24. 25. 26. 27. Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive, horizons .................... Will surface casing protect fresh water zones ..... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore .......... ,.. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is"ad'ivert'er'§YSt'em"re~u'ir~:fl ........... Are necessary diagrams of diVerter anu'ouP'equ~pmen.": Does BopE'have sUffiCient pressure rating - TeSt to ~,ff~ psig ..~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements .............................................. _~ u~ 177'£P Additional Remarks: O Geology: JAL X En i erin I, CS rev: 03/13/85 6.011 INITIAL GEO. UNIT .ON/OFF POOL CLASS STATUS AREA NO. SHORE , · Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologicallY organize this category of information. ~ERIFICh~T~ ,VP nlo,g02 VERIFICATION LISTING PAGE WELL SITE DATA AND TABLES ARE NOT INCbl. JD~D IN THIS LISTING WAVEFORMS AND FAST CHANNEL DATA ABE NOT INCLUDED IN THIS LISTING ,VP OIO,H02 VERIFfCATION LTSTING :* R~E[, HERDER )ATE :85/04/17 )RIG~N : ~ONT~NHATION # 'REVCO!IS REEL ~OMMFN~S : "* TRPE HERDER ** ~ERV~CF HAME IEDTT )ATE :85/04/17 )R~G~N :0000 rAPE N~ME ~0303 ~ON~INUA~ION ~ ~0! EOF #* F~LE HERDER ** mILE NRM~ :EDTT ,001 JATE ~AXI~I{~ LENGTH : 1024 ~IL~ TYP~ ~RE ~OU$ F~bE COMMENTS ** ******************************************************************************* * R A SCHLUMBERGER * b SKA COMPUTING CENTER * ************************************************************************************* OMPANY = ATLANTIC RiCHFIeLD COMPANY F,IEbD = KUPRRUK ,VP 010,M0~ VERIFICATION LISTING PAGE 3 IOUNTY ;T&TF : ALASK~ rOB NUMBER AT ACC; 70303 IUN #1. DATE bOGGED: 13'APR'85 ,DP= !ASING = 9.625" ~YPE FY,UID = XC-POLYMER ,E.$ITY - 10.2 LB/G rISCOSITY = 36~0 S 'H = 8, 'bUIO LOSS = 7,2 C3 3361' ' BTT $%ZE = 8,5" R~ = 4,101 _e 75,0 DF = 5,600 ~a 75,0 DF = ?.,440 · 75 0 DF = 2.121. ~ 14§.o ~ IATR]X S~NDSTONE '**** THIS DAT~ HAS NOT BEEN DEPTH SHIFTED - OVERhAYS FIEbD PRINTS ***** ******************************************************************************* DATA FORMAT RECORD TYPE SIZE REPR CODE ENTRY 2 1 66 0 4 1 66 1 8 4 73 60 9 4 65 .'lin 1.6 I 66 1 0 i 66 0 )ATU~ SPECIFICATION BbOCK$ 4NMM SERVICE SERVICE UNIT APl Ap1 API APl FISE SIZE 8P5 REPR PROCESS ,VP O10.H02 VERIFICATION hlSTIMG ORDER LOG TYPE CLASS MOD NO, FT 00 000 O0 0 0 OH~M O0 220 01 0 0 OH~N O0 ~20 46 0 0 OH~M O0 120 44 0 0 ~V O0 010 O1 0 0 GABI O0 310 01 0 0 GAPI O0 3i 0 O1 0 0 ~N O0 280 O1 0 0 ~/C3 O0 350 02 0 0 ~/C3 O0 356 O1 0 0 O0 420 01 0 0 O0 000 O0 0 0 PU O0 890 O0 0 0 CPS O0 330 31 0 0 CPS O0 330 30 0 0 PAGE 4 CODE ¢OCTAL) 68 00000000000000 68 00000000000000 68 00000000000000 6B 00000000000000 68 00000000000000 68 O0 000000000 000000 0 0000 68 000 0 O0 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 )EPT 7703 0000 SFI.,U 3 6621 ,)EPT }HOB {PHI 000 0000 8FLU 38.0371 NCNL qPHI 3328.5000 8F[,U -46,O000 GR 2.0625 DRHO 59.2285 NCNb 2.5605 66.3750 CALI .~215 ILD 2.4727 !bM 34 NRRT 3, 5 RNRA 192~,0000 WCNb 588. ;ION # : UM LENGTH : 1024 ~ TYPE ~' 5~,96,97 · 4063 GR -0.3853 NRAT 1492.0000 FCNL ********** EOF ~I0~3 CALI 4.40 3 RNRA 328 .:2500 3,0410 8.5000 3.8516 3984 8 200~,0000 4,8125 ,5430 J* TAPF TRAILER ** 5ERVTC~ NAME :MDIT DATE :85/"04/~,.7 5RSGIN ~0000 tAPE NAM~ :0303 CONTINUATION # :01 ~VP OlO.g02 VERIFICATION LTSTING IEXT TAPE NA~E : ;* RMEL TR~ILE~ ** ;ERYYCE NAME :EDIT )ATE )RZGIN = ~ON~TNIIATI~N # IEXT RFEL NAME ~OMM~NT$ : ********** EOF ********** ********** EOF
