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Home My WebLink About200-026MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-22A KUPARUK RIV UNIT 3K-22A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 3K-22A 50-029-22759-01-00 200-026-0 N SPT 3925 2000260 1500 1260 2520 2480 2460 REQVAR P Josh Hunt 5/9/2025 MIT-T required by AIO 2B.013 This well is a monobore and has no OA. 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 3K-22A Inspection Date: Tubing OA Packer Depth 350 430 450 450IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250510094315 BBL Pumped:1.2 BBL Returned:0.8 Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 99 9 9 9 AIO 2B.013 monobore James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 14:06:33 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-22A KUPARUK RIV UNIT 3K-22A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 3K-22A 50-029-22759-01-00 200-026-0 N SPT 3925 2000260 1500 1250 1440 1450 1450 REQVAR P Josh Hunt 5/9/2025 MIT-IA required by AIO 2B.013 This well is a monobore and has no OA. 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 3K-22A Inspection Date: Tubing OA Packer Depth 360 2520 2410 2380IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250510095107 BBL Pumped:1.2 BBL Returned:1.1 Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 9 9 99 9 999 9 9 9 AIO 2B.013 monobore James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 14:03:58 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-22A KUPARUK RIV UNIT 3K-22A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 3K-22A 50-029-22759-01-00 200-026-0 N SPT 3925 2000260 1500 1125 1350 1350 1380 REQVAR P Austin McLeod 5/7/2023 Two year MITIA. Monobore. AIO 2B.013. 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 3K-22A Inspection Date: Tubing OA Packer Depth 0 2490 2350 2325IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230507191424 BBL Pumped:2 BBL Returned:1.5 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 999 9 9 9 9 9 Two year MITIA.AIO 2B.013. James B. Regg Digitally signed by James B. Regg Date: 2023.06.02 11:23:25 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-22A KUPARUK RIV UNIT 3K-22A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 3K-22A 50-029-22759-01-00 200-026-0 N SPT 3925 2000260 1500 1100 2500 2450 2435 REQVAR P Austin McLeod 5/7/2023 Two year MITT. Plug @ 8225 ft MD. Monobore. AIO 2B.013. 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 3K-22A Inspection Date: Tubing OA Packer Depth 0 0 0 0IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230507191134 BBL Pumped:1 BBL Returned:0.8 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 999 99 9 9 9 Two year MITT.AIO 2B.013. James B. Regg Digitally signed by James B. Regg Date: 2023.06.02 11:25:32 -08'00' Originated: Delivered to:3-Aug-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 3F-14 50-029-21500-00 907249583 Kuparuk River Packer Setting Record Field- Final 7-Jul-21 0 12 3H-31A 50-103-20205-01 n/a Kuparuk River Plug Setting Record Field- Final 26-Jul-21 0 13 3K-22A 50-029-22759-01 n/a Kuparuk River Plug Setting Record Field- Final 9-Apr-21 0 145678910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:08/03/2021Wd͗ϮϬϬϬϮϲϬͲ^Ğƚ͗ϯϱϰϴϴBy Abby Bell at 2:11 pm, Aug 03, 2021 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 13, 2021 TO: Jim Regg 5't etzoz'l �� SUBJECT: Mechanical Integrity Tests P.1.Supervisor 2 l ConocoPhillips Alaska, Inc. 3K -22A FROM: Austin McLeod KUPARIIK RIV UNIT 3K -22A Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry VP-- NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K -22A Insp Num: mitSAM210506071636 Rel Insp Num: API Well Number 50-029-22759-01-00 Inspector Name: Austin McLeod Permit Number: 200-026-0 Inspection Date: 5/5/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - Well 3K zzA Type Inj --N ITV 3925 Tubing ns zsoo . zaoo 237s T- — - PTD 2000260 Type Test SPT TI est psi 1500 IA 290 420 _ 420 420 BBL P P 1.2 'BBL Returned: 1 OA — — I nte REQVAR - P/F P Notes: 2 year MITT. A10 2B.013. Test to prove tubing below shallow set packer. Plug @ 8251 ft MD. Monobore Thursday, May 13, 2021 Page 1 of I MEMORANDUM TO: Jim Regg I P.I. Supervisor FROM: Austin McLeod Petroleum Inspector Well Name KUPARUK RIV UNIT 3K -22A Insp Num: mitSAM210506072359 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 13, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3K -22A KUPARUK RIV UNIT 3K -22A Src: Inspector Reviewed B--y:rpn PA. Supry 1 — Comm API Well Number 50-029-22759-01-00 Inspector Name: Austin McLeod Permit Number: 200-026-0 Inspection Date: 5/5/2021 — Packer Depth Pretest Initial 15 Min Well 3K-zzA .TypeInj �N�TVD 3925 Tubing 800 - 940 - _-960 PTD 2000260 - Type Test sPT Test psi, soo lA� 310 2490 - 2365 _ BBL Pumped: 4 _BBL Returned: L OA Interval REQVAR P/F P Notes: 2 year MITIA. ATO 26.013. Shallow packer. Monobore 30 Min 45 Min 60 Min 960 -�--_— Thursday, May 13, 2021 Page I of I MEMORANDUM TO: Jim Regg P.1. Supervisor ��S'� S(3t101 - FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 30, 2019 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, INC. 3K -22A KUPARUK RIV UNIT 3K -22A See: Inspector Reviewed By�:-r�!s P.1. Supry ._l VI` Comm Well Name KUPARUK RIV UNIT 3K -22A API Well Number 50-029-22759-01-00 Inspector Name: Bob Noble Insp Num: mitRCN 190528145156 Permit Number: 200-026-0 Inspection Date: 5/28/2019 ' Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min p 3K -22A Type Inj BBL Returned: i s 2430 1420 - Well � � Test SPT Test psi isao OA to � 2520 �- :.-------� N- TVD 3925 Tubing ago a3o PTD -L 2000240 -Type 2230 2320 , BBL Pum ed: i.4 Interval RRpVAR --]P FF P— — -- - Notes: MIT -IA every 2 years to demonstrate production casing integrity per AIO 25.013. Monobore well. Thursday, May 30, 2019 Page I of I MEMORANDUM TO: Jim Regg l�/t P.I. Supervisor I-l-jG 5'7y.111 FROM: Bob Noble Petroleum Inspector Well Name KUPARUK RIV UNIT 3K -22A Insp Num: mitRCN190528144510 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 28, 2019 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, INC. 3K -22A KUPARUK RIV UNIT 3K -22A Sre: Inspector Reviewed By: P.I. Supry sl?— NON -CONFIDENTIAL Comm API Well Number 50-029-22759-01-00 Inspector Name: Bob Noble Permit Number: 200-026-0 Inspection Date: 5/28/2019 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K -22A - Type Inj N_TVD 3925 -..Tubing 1680 2510 2490 _ 1410 - PTD 2000260 - iType Test! SPT Test psi 1500 IA 10 10 10 0 BBL Pumped: 0.5 - ,BBL Returned: 0.5 - OA Interval REQVAR p/F Notes: MIT -T every 2 years against a plug set at or below 8200' MD as per AIO 28.013. Mono bore well. Tuesday, May 28, 2019 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,May 22,2017 TO: Jim Regg `ef 517.7'117 P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-22A FROM: Lou Laubenstein KUPARUK RIV UNIT 3K-22A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-22A API Well Number 50-029-22759-01-00 Inspector Name: Lou Laubenstein Permit Number: 200-026-0 Inspection Date: 5/16/2017 Insp Num: mitLOL170516165312 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-22A Type Inj N TVD 3925 Tubing 1585 2510 ' 2480 • 2465 PTD 2000260 - Type Test SPT Test psi 1500 • IA 575 640 650 ' 650 . BBL Pumped: 0.4 BBL Returned: 0.6 OA Interval REQVAR P/F P Notes: MITT per AIO 2B.013 A plug was set in the tubing at 8220ft for this test. r SCAMS L 1 Z017. Monday,May 22,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,May 22,2017 TO: Jim Regg 7 5 I22 It 7 P.I.Supervisor �� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-22A FROM: Lou Laubenstein KUPARUK RIV UNIT 3K-22A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry.� t-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-22A API Well Number 50-029-22759-01-00 Inspector Name: Lou Laubenstein Permit Number: 200-026-0 Inspection Date: 5/16/2017 Insp Num: mitLOL170516170003 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-22A • Type Inj N TVD 3925 Tubing 1590 1750 1750 • 1750 PTD 2000260 Type Test SPT Test psi 1500 IA 520 2315 . 2295 - 2285 BBL Pumped: 1.2 - BBL Returned: 1.1 ' OA Interval REQVAR P/F P ✓ Notes: MITIA per AIO 2B.013 SCANNED .jiw ,.. I 1 H0?. Monday,May 22,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,June 01,2015 P.I.Supervisor �i 614 I' SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-22A FROM: Jeff Jones KUPARUK RIV UNIT 3K-22A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Tag— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-22A API Well Number 50-029-22759-01-00 Inspector Name: Jeff Jones Permit Number: 200-026-0 Inspection Date: 4/14/2015 Insp Num: mttJJ150601113709 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-22A Type Inj N'TVD 3925 Tubing 2110 2280 2300 2300 PTD 2000260 - Type Test SPT Test psi 1500 - IA 420 2980 - 2840 - 2820 Interval 'REQVAR— P/F P , OA Notes: MIT-IA per AIO 2B.013 SCOW .JUL 132.U1 Monday,June 01,2015 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,June 01,2015 Jim Regg � P.I.Supervisor ` lc�e 6(u- 115 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-22A FROM: Jeff Jones KUPARUK RIV UNIT 3K-22A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry -2,--- NON-CONFIDENTIAL — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-22A API Well Number 50-029-22759-01-00 Inspector Name: Jeff Jones Permit Number: 200-026-0 Inspection Date: 4/14/2015 lnsp Num: mitJJ150601122710 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I 3K-22A - Type Inj N"TVD 3925 • Tubing 2100 • 3000 - 2960 -I 2940 - REQVAR ''Type psi P ✓f 580 - 580 580 PTD 2000260 T e Test SPT Test 1500 I IA I 520 Interval P/F I OA Notes: MITT AIO 2B-013 WRP set @ 8260'MD %DIED J U L 1 32015 Monday,June 01,2015 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,April 17,2013 TO: Jim Regg '7 P.I.Supervisor l'e,,171 4'(76`r 3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-22A FROM: Jeff Jones KUPARUK RIV UNIT 3K-22A Petroleum Inspector Src: Inspector Reviewed By:, P.I.Supry �� NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-22A API Well Number 50-029-22759-01-00 Inspector Name: Jeff Jones Permit Number: 200-026-0 Inspection Date: 4/5/2013 Insp Num: mitJJ130416142349 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min T PTD 2000260 Type Test jTVD 39zs IA Iowa Ills vial Ital Well A 'Type In' 3 Test psi! 1500 OA i Interval REQVAR P/F j P !Tubing 1640 f 3000 2930 2920 I Notes: MIT-T per AIO 2B.013 0.8 BBLS diesel pumped. I well inspected;no exceptions noted. SCOW FEB 2 ZD1 Wednesday,Ap ril 17,2013 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,April 17,2013 Jim Regg P.I.Supervisor (' 4I l`3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-22A FROM: Jeff Jones KUPARUK RIV UNIT 3K-22A Petroleum Inspector Src: Inspector Reviewed Bp_ P.I.Supry'J ae-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-22A API Well Number 50-029-22759-01-00 Inspector Name: Jeff Jones Permit Number: 200-026-0 Inspection Date: 4/5/2013 Insp Num: mitJJ130416142713 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min IT N ' 3925 Well 3K-22A iype Inj TVD IA 960 2820 2740 2710 PTD OA - - —2000260 Type Test!SPT Test p si' 1500 -- -- _ - � Interval REQVAR 1P/F P ✓ Tubin g l 576 785 740 - 751 • Notes: MITIA per AIO 2B.013 1.1 BBLS diesel pumped. I well inspected;no exceptions noted. _ SCANNED FEB 2 6 2.014 Wednesday,April 17,2013 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, April 11, 2011 TO: Jim Regg ) 1/ , 9 I I I it P.I. Supervisor l SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K -22A FROM: Matt Herrera KUPARUK RIV UNIT 3K -22A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3K -22A API Well Number: 50- 029 - 22759 -01 -00 Inspector Name: Matt Herrera Insp Num: mitMFH1 1 0408 1 1 3 709 Permit Number: 200 -026 -0 Inspection Date: 4/7/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-22A' Type Inj. N ' TVD 3925 IA 459 I 2000 - 1942 I 1928 - P. T.D 2000260 lTypeTest SPT Test psi 2000 OA Interval RE Q V AR p/F P - Tubing 745 862 891 900 Notes: MITIA performed for 2 yr variance required per AA for paker depth in conjunction with perf location. k_."1--0 Z8. 01 Monday, April 11, 2011 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday, April 11, 2011 Jim Regg J e ft P.I. Supervisor i 'l i Is • SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K -22A FROM: Matt Herrera KUPARUK RIV UNIT 3K -22A Petroleum Inspector Src: Inspector Reviewed By P.I. Supry �-- NON CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3K - 22A API Well Number: 50 029 - 22759 - 01 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH110408114436 Permit Number: 200 - 026 - Inspection Date: 4/7/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K -22A -' Type Inj N I TVD 39 IA 486 537 540 540 P.T.D 2000260 TypeTest SPT Test psi 2000 • OA Interval REQVAR P/F P , Tubing 1213 2020 " 1979 1970 Notes: MITT on Monobore completion per 2 yr variance for AA on Packer depth in conjunction with perf location. APR 1 4 20l Monday, April 11, 2011 Page 1 of 1 Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Friday, April 08, 2011 12:47 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: AA required MIT's on 3K -22A Attachments: MIT KRU 3K -22A 04- 07- 11.xls c� c3 9 (.o All, Attached is a copy of the witnessed MITT and MITIA for 3K -22A that was performed on 04/07/11. Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 .g AU Iwo 1 8 ZUUb 8/4/2011 • MEMORANDUM To: Jim Regg ~~ ~ ~ ~ ~ 4~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 20, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-22A KUPARUK RIV UNIT 3K-22A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV UNIT 3K-22A API Well Number: 50-029-22759-01-00 Inspector Name: Chuck Scheve Insp Num: mitCS090405150834 Permit Number: 200-026-0 Inspection Date: 4/5/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~- Well 3K-zzA Type Inj. N 'I'mo 3925 '~ IA 400 400 ~ 400 400 P.T.D 2oooz6o TypeTest SPT Test psi Isoo OA Interval OTHER per, P / Tubing 2050 3470 3460 3460 Notes' ~ MITT of Mono-bore completion. Wednesday, May 20, 2009 Page 1 of 1 MEMORANDUM To: Jim Reg P.I. Supervisor ~Q~j ~ ~' I~j FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, April 08, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHII.LIPS ALASKA INC 3K-22A KUPARUK RI V UNIT 3K-22A Src: h~spector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ('~ Comm Well Name. KUPARUK RIV UNIT 3K-22A API Well Number 50-029-22759-01-00 Inspector Name: Chuck Scheve asp rj~: mitCS090405 1 5083 4 Permit Number: 200-026-0 ~ Inspection Date• 4/5/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-22A TYPe ~]• N TVD 3925 '~ IA 400 4~ 400 400 P.T. zoooz6o TypeTest SPT Test psi 15~,~y2s- OA Interval °T~R P/F P y ' Tubing zoso 34~o r 3460 3460 ~' Notes• 13i-annual MITT of Mono-bore completion. 15 J I SUc~ ~I ~ ~kjJ ,~qc 25.4 i 2-) ~e.~~4~~~~~~? ~~~ ~~ ~k I ~.1~; Wednesday, Apri108, 2009 Page 1 of 1 Kuparuk River Unit MITIAs Regg, James B (DOA) • Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] ~ l ~~ ~~ Sent: Saturday, March 01, 2008 10:34 AM ~ ~, ~ ~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Subject: Kuparuk River Unit MITIAs Attachments: MIT KRU 1J-122 02-29-08.x1s; MIT KRU 3K-22A 02-29-08.x1s; MIT KRU 1J-176 02-29-08.x1s «MIT KRU 1J-122 02-29-08.x1s» «MIT KRU 3K-22A 02-29-08.x1s» «MIT KRU 1J-176 02-29-08.x1s» All, Attached for your records are the MITIAs conducted on 2/29/08. Please contact myself or Brent Rogers if you have any questions or comments. Martin Walters Problem Wells Supervisor ConocoPhillips Alaska Inc. 907-659-7224 ado ' o ~.~ 3/3/2008 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD / UN{T /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc Kuparuk /KRU / 3K 02/29/08 Greenwood /Johnson waived by Bob Noble ~~~ ~31~ Packer Depth Pretest Initial 15 Min. 30 Min. Well 3K-22A T e In'. W TVD 3,925' Tubing 1,650 1,650 1,650 1,650 Interval I P.T.D. 2000260 T e test P Test psi 1500 Casing 525 3,000 3,000 3,000 P/F P Notes: Initial MITIA post SC patch as per sundry 306-407 OA Well T e Inj. TVD Tubing Interval P.T.D. Ty e test Test si Casing P/F Notes: OA Weil Ty e lnj. TVD Tubin Interval P.T.D. T e test Test si Casin P/F Notes: OA Well T pe Inj. TVD Tubing Interval P.T.D. Type test Test si Casing P/F Notes: OA Well T pe In'. TVD Tubing Interval P.T.D. T pe test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water 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 T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 3K-22A 02-29-O8.xls Question re 10-404 for 3K-2~ TD 200-026 Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Tuesday, February 26, 2008 1:33 PM To: Maunder, Thomas E {DOA) Subject: RE: Question re 10-404 for 3K-22a PTD 200-026 Attachments: 3K-22A 10-403 10-404 SC Repair 12-25-06.x1s Tom, • Page 1 of 2 Enclosed is the revised 10-404 for 3K-22a. I have modified the T/I/O's to read T/I as they should and corrected the erroneous pressure reading. The summary tab has been corrected. Let me know if you have any questions or need anything else. I will update the files on our end to reflect the correct data. Thanks Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 ~~~~~ FEB ~ 6 200' From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.govj Sent: Monday, February 25, 2008 9:05 AM To: NSK Well Integrity Proj Subject: RE: Question re 10-404 for 3K-22a PTD 200-026 Perry, I looked at the report that was filed and I see what you mean. It is stated that the lA was tested, however in the TIO "listing" the pressure is given for the "O". You can send in the revised report as an attachment to your reply to this message. Then I will place both in the files. Call or message with any questions. Tom Maunder, PE AOGCC From: N5K Well Integrity Proj [mailto:N1878@conornphillips.com] Sent: Sunday, February 24, 2008 7:14 AM To: Maunder, Thomas E (DOA) Subject: Question re 10-404 for 3K-22a PTD 200-026 Tom, 2126/2008 Question re 10-404 for 3K-22a PTD 200-026 • Page 2 of 2 • It has come to my attention that there are a number of typographical errors in the 10-404 that was submitted to your office post surface casing repair on well 3K-22a PTD # 200-026 sundry # 3~-407. In the attached daily report of well operations the well head pressures are mistakenly reported in T/l/O fashion referring to tubing, inner annulus, and outer annulus respectively. 3K-22a is a single surface casing well and does not have an outer annulus. The 1A pressures were mistakenly reported as OA pressures. In addition the 30 min MIT pressure reading is erroneously reported as 29000 psi and should read 2900 psi. I would like to correct the problems in the daily report but am unsure of how to proceed. Wbukt it be possible to submit an amended daily report'? Please advise. Thanks Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 2/26!2008 ~~ L_J 3K-22A DESCRIPTION OF WORK COMPLETED SUMMARY Date ~ Everit Summary 12/10/2007 12/13/2007 Purged Cond ~ lA with nitrogen prior to starting. Using welders cut and removed 2 -18" x 18" windows on conductor casing. Welders then cut out an additional 10" x 18" for a total of 2 - 18" x 28" windows near top of mandrel hanger. Chipped cement out of top of conductor via ~ casing window cut outs and cleaned SC surface for UT. Purged IA with nitrogen prior to start up. Assisted welders with the cutting/removal of 7' 6" of the conductor casing. Chipped cement and cleaned up SC for UT at the bottom of the exposed pipe (Cleaned SC with wire wheel grinder, purged IA with nitrogen to locate leak ~ 4' 9" below I mandrel hanger (measurement from top of hanger). SC patch weld -Complete. Purge nitrogen down annulus while we~ing. Patch Welded as per M.E. specs. Weld 29" .500" upper wedding band in no-go style including tie in seal weld to mandrel hanger. Bottom portion of upper wedding band is not welded only shouldered out SC collar. 12" lower 500 wall wedding band. Install .375" SC patch that straddles SC collar. Total patch length from bottom of mandrel hanger to knwer most wedding band is T 1". 1/1/2008 M1T IA SC repair passed. Pressure up IA to -1000 psi wait r 5 minutes no leaks, pressure to 2000 psi wait for 5 minutes no leaks, pressure to 3000 psi started MIT lA, Initial TA = 0/0, start = 0!3000, 15 min. = 0/2925, 30 min. = 0!2900, 45 min. 0/2900, 60 min. = 012900. Bleed down OA to 0. Final T/1=010. Wra SC with Denso wrap. 1/5/2008 install new conductor, Tfl =010, Assist welders installing T6" of 16" 62.5# API 5L Gr 8 Conductor casing. • ConocoPhillips ~s~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 L_J RECEI~/E!~ JAN ~ ~ 2.~J Alaska Oil & Gas Cans. t~ommissi~r~ anchorage January 06, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission ~; ~, "~~) ~~~ ~ ~~ ~~~ 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder:.~~ „ r3a ~ ~~ , Cam _...__.., Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. wells 3K ~(PTD 200-026). The report records the completion of the surface casing excavation, inspection, and repair of Kuparuk we113K-22. Please call myself or MJ Loveland at 659-7043 if you have any questions. Well Integrity Project Supervisor • • Name of Recipient Page 2 of 2 01/07/08 Delete the section break above to remove the second page • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION R~~E~ V f~L1 REPORT OF SUNDRY WELL OPERATI_QNS 1. Operations Pertormed: Abandon ^ Repair Well^ • Plug Pertoretions ^ Stimulate ^ O her ~ ~ ~nchora ,e Alter Casing '~~jy;',~'! Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ~ 200-026 / ' 3. Address: Stretigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22759-01 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 7-; f t, r.L3-d'b 3K-22A 8. Property Designation: 10. Field/Pool(s): ADL 25519 ALK 2555 Kuparuk River Field /Kuparuk Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 11290' feet true vertical 6668' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' Surface 4887' 7 518" 4887' 4091' Liner 6498' 41/2" 11175 6661' Perforation depth: Measured depth: Intervals from 9195-11 060' true vertical depth: Intervals from 6637-6667' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 4677' MD. Packers &SSSV (type & measured depth) Baker SABL M/ZXP Liner Packer as~~' SSSV= NIP SSSV= 524' 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 Casin Pressure Tubin Pressure Prior to well operation na na na na na Subsequent to operation na na na na na 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 ' Daily Report of Wetl Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ Q WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 306-407 Contact Printed Name Perry Klein Title Well Integrity project Supvenrisor Signature Phone 659-7043 Date 1-6-2008. Form 10-404 Revised 04/2004 ~' a ~ ~ ~3 o5S Submit Original Only • • 3K-22A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/10/2007 Purged Cond & IA with nitrogen prior to starting. Using welders cut and removed 2 - 18" x 18" windows on conductor casing. Welders then cut out an additional 10" x 18" for a total of 2 - 18" x 28" windows near top of mandrel hanger. Chipped cement out of top of conductor via casing window cut outs and cleaned SC surface for UT. 12/13/2007 12/15/2007 12/30/2007 1/1/2008 1 /5/2008 Purged IA with nitrogen prior to start up. Assisted welders with the cutting/removal of 7' 6" of the conductor casing. Chipped cement and cleaned up SC for UT at the bottom of the exposed pipe Cleaned SC with wire wheel grinder, purged IA with nitrogen to locate leak @ 4' 9" below mandrel hanger (measurement from top of hanger). SC patch weld -Complete. Purge nitrogen down annulus while welding. Patch Welded as per M.E. specs. Weld 29" .500" upper wedding band in no-go style including tie in seal weld to mandrel hanger. Bottom portion of upper wedding band is not welded only shouldered out SC collar. 12" lower 500 wall wedding band. Install .375" SC patch that straddles SC collar. Total patch length from bottom of mandrel hanger to lower most wedding band is 7' 1 ". MIT IA SC repair passed. Pressure up IA to -1000 psi wait for 5 minutes no leaks, pressure to 2000 psi wait for 5 minutes no leaks, pressure to 3000 psi started MIT IA, Initial T!I/O = 0/0/0, start = 0/0/3000, 15 min. = 0/0/2925, 30 min. = 0/0/2900, 45 min. 0/0/29000, 60 min. _ 0/0/2900. Bleed down OA to 0. Final T/I/O = 0/0/0. Wrapped SC with Denso wrap. Install new conductor, T/I/O = 0/0/0, Assist welders installing 7'6" of 16" 62.5# API 5L Gr B Conductor casing. i • ~'<~~(='c~lic~coPlullil~ ~~1~1La, Iiic 7u plic~to i cc~p~~ri~lit b~- t.'onocoPlulli1r .=~1~~~ k~, Inc. ~~lid ~11ll1C~t lie l~le~~~ecl or pl~bli~liecl ~~-itliout eZl~re~s i~-ritten cuii~eiit f c.'~~liacc~Plullip~ ~~la~k~~ a~ • LVI~ LVI U RAN U U Nt . Mate 01 Alaska Alaska Oil and Gas Conservation comm. DATE: Tuesday, May 0 I, 2007 SLBJECT: 'VIechanical [ntegnty Tests COèJOCOPHILUPS\LASKA INC TO: Jim Regg P.I. Supervisor "~-' ~~ ~¡ ¡ 3K-22A ;),gO-D~ FROM: John Crisp Petroleum Inspector KUPARTJK RIV U'\)IT 3K-22A Src: Inspector Reviewed Bv: ·~v _ P.I. Suprv '- U,;;r-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3K-22A Insp Num: mitJCr070410092100 ReI Insp N urn: API Well Number: 50-029-22759-01-00 Permit Number: 200-026-0 Inspector Name: John Crisp Inspection Date: 4/3/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. W~" 3K-22A ;~i;;j~G-VD 3925--¡--iA----c6~~T;~-----¡--ru;_--~~~-----,---- P.T.Di 2000260 ITypeTest i SPT. Test psi ~---oA--T-------'------------;-- -~--~--- __. 1 . I . __~_--¡------_ -L._~_~_l_____ ~!!L. REQVAR _~~ _ P__ ~Tubing ·.~220~_ 2540__------=-5~_~_=_~___~______ Notes: 1 bbl pumped for test. Tubing test with TTP set. s(;ANNED MA~' 09 2007 Tuesday, May 01,2007 Page 1 of 1 . MEMORANDUM State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor '\<c?i1 4/1'1D7 DATE: Monday, Apri123, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-22A KUPARUK RIV UNIT 3K-22A ;).bO - ö')k FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv Jf5jZ--- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3K-22A API Well Number: 50-029-22759-01-00 Inspector Name: John Crisp Insp N urn: mitJCr07041 00920 I 1 Permit Number: 200-026-0 Inspection Date: 4/3/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-22A Type Inj. N TVD 3925 IA 700 2540 2490 2480 P.T.D 2000260 TypeTest SPT Test psi 1500 OA Interval REQVAR P/F P ../ Tubing 1220 t370 1370 1370 Notes: 2 bbl's pumped for test. A/l::r::4 - J:.A SCANNED APR 3 0 2007 Monday, April 23,2007 Page I of I . MEMORANDUM State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg ~ I { P.I. Supervisor ì \ær5 4- U-Ò7 DATE: Monday, April 23, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-22A KUPARUK RIV UNIT 3K-22A -,0# ~OO FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ,ít-Sí2- Comm Well Name: KUPARUK RIV UNIT 3K-22A API Well Number: 50-029-22759-01-00 Inspector Name: John Crisp Insp N um: mitJCr0704 I 0085907 Permit Number: 200-026-0 Inspection Date: 4/3/2007 Rei Insp N um: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-22A Type Inj. N TVD 3925 IA 680 730 730 730 P.T.D 2000260 TypeTest SPT Test psi 981.25 OA Interval REQV AR P/F P <../ Tubing 1220 2540 2510 2500 Notes: Monobore injector. I bbl pumped for test pressure. Tubing PT with TTP set. M.I'T -j NON-CONFIDENTIAL Monday, April 23,2007 Page 1 of 1 RE: 3K-22A PTD # 200-026 Surface casing leak update . . Tom, The intent of the original sundry was to proactively excavate and repair any damage found. We haven't identified the leak depth yet. Diagnostics are planned for later this week. We suspect the leak is very shallow, a foot or two down from surface but do not have any hard evidence to back that up yet. let me know if you have any other questions. Perry ~Me.D APR 1 0 2007 From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, April 09, 20078:00 AM To: NSK Problem Well Supv Cc: James Regg Subject: Re: 3K-22A PTD # 200-026 Surface casing leak update Perry, It appears that there already is a sundry (306-407) in place for the excavation repair. Is there any estimate of the depth of the leak? Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 4/7/20077:43 PM: Jim & Tom, On 04-06-07 CPAI set a wire line retrievable plug at 4706'. The well is secured. Plan forward will be to excavate and repair the surface casing leak. Please let me know if you have any questions. Sincerely, Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 10f2 4/9/2007 1 :59 PM 3K-22 PTD # 200-026 Single surface casing produced water injector ... f . . Jim & Tom, 3K-22 PTD # 200-026 Single surface casing produced water injector developed a surface casing leak. The WRP, that was set for the recent MITT 1 MITIA, was pulled yesterday and the well was placed on production. The surface casing begin leaking fluid to the conductor today. TII = 175010 psi The well has been shut in and we are making plans to kill the well with weighted brine and secure it with a WRP set below the packer at 4677'. Please let me know if you have any questions. Sincerely, Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com 1 of 1 4/9/2007 7:52 AM MIT KRU 3K-22a 04-03-07 per Administrative Approval AI02B.013 . . «MIT KRU 3K-22a 04-03-07.xls» Jim, Tom, & Bob, Enclosed are the MITT & MITIA results to the 2 year variance testing required for continued operation of 3K-22. 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 n161 11 Content-Description: MIT KRU 3K-22a 04-03-07.xls MIT KRU 3K-22a 04-03-07.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 1 of 1 4/9/2007 7:52 AM . . 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 OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk / KRU /3K-22a 04/03/07 Perry Greenwood / Ron Bates John Crisp ~o~ ~ÐQ Packer Depth Pretest Initial 15 Min. 30 Min. Well ! 3K-22a I Type Ini. I N TVD I 3,925' Tubing 1220 2540 2510 2500 Interval V P. T. D .12000260 I Type test I P Test psil 1500 Casing 680 730 730 730 PtFl P Notes: MIT & MITIA per Administrative Approval OA AI02B.013 requirements Well!3K-22a I Type Inj. N TVD 3,925' Tubing 1220 1370 1370 1370 Interval V PTD.12000260 I Typetesd P Test psi! 1500 Casing 700 2540 2490 2480 P/F P Notes: MIT & MITIA per Administrative Approval OA A102B.013 reauirements Weill I Type Inj.1 TVD I Tubing Interval p.T.D.1 Typetesd Test psi! Casing P/FI Notes: OA Weill I Type Inj.1 TVD ! Tubing Interval I PTD.I I Typetesd Test psi I Casing PtF Notes: OA Weill I Type Ini.1 TVD I Tubing Interval! PTD.I I Type test! Test psi! Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval P.T.D.I I Type test I Test psil 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 o = Other (describe in notes) MIT KRU 3K-22a 04-03-07.xls . . SARAH PALIN, GOVERNOR AI.ASIiA. OILAlWD GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 c't·'ii,,~\.\NEû \.~''-Jn;~''', '" t" " " ,../,} Re: Kuparuk River Field, Kuparuk River Oil Pool, 3K-22A d.00~ D~ Sundry Number: 306-407 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. Sincerely, DATED this~day of December, 2006 Encl. f}TS 12./2. 7 (¡ STATE OF AlASKA k-~ RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION ";Ÿ) DE C 2 6 200b APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons. Commission 20 MC 25.280 Operational Shutdown 0 Plug Perforations 0 Perforate New Pool 0 . 1. Type of Request: o o o Suspend 0 Abandon Alter casing Repair well Change approved program 2. Operator Name: ConocoPhi/lips Alaska, Inc. 3. Address: Pull Tubing o o Perforate 0 o Time Extension o o o Other 0 Waiver Stimulate Re-enter Suspended Well 4. Current Well Class: Development 0 Stratigraphic 0 5. Permit to Drill Number: 200-026 6. API Number: Exploratory 0 Service 0 P. O. Box 100360, Anchorage, Alaska 99510 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: 50~029-22759-01 8. Well Name and Number: Spacing Exception Required? 9. Property Designation: ADL 25519 ALK 2555 12. Total depth MD (ft): 11290' Casing Yes 0 Total Depth TVD (ft): Effective Depth MD (ft): 6668' Length Size CONDUCTOR 121' 4887 6498 16" Surface 75/8" 41/2" Liner Perforation Depth MD (ft): Intervals from 9195-11060' Packers and SSSV Type: Baker SABL M/ZXP Liner Packer SSSV= NIP Perforation Depth TVD (ft): Intervals from 6637-6667' 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for Commencing Operations: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and corre Printed Name MJ Love/an March 1, 2006 Date: Signature No 0 10. KB Elevation (ft): RKBO' PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): 3K-22A 11. Fie/d/Pool(s): Kuparuk River Field / Kuparuk Oil Pool Junk (measured): MD TVD 121' 121 4887' 4091 11175 6661 Burst Collapse Tubing Size: 4-1/2" Tubing Grade: L-80 Tubing MD (ft): 4677' Packers and SSSV MD (ft) 4677' SSSV= 524' 14. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 owledge. Contact: Title: Phone 659-7043 MJ Loveland/Jerry Dethlelfs Well Integrity Project Supervisor Date 12/25/06 Commission Use Only Sundry Number: 7 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Location Clearance 0 Mechanical Integrity Test 0 Other: "::~::A,<~\ -S::,",S.~IéL~\-~Qe,\-Ð~~C)\~~'~ \ù ~t\IK>S ~O-~~~ / re~\, <=-0 """-é>l'-- ~ ~a~ O\- ~,\>ú..\ ç- Subsequent Form Required: 4 \) '-\ RBDMS Bf~{2 '7 :!OOfi Approved by: Form 10-403 Revised 06/2006 APPROVED BY . . ConocoPhillips Alaska, Inc. Kuparuk We1l3K-22A (PTD 200-026) SUNDRY NOTICE 10-403 APPROVAL REQUEST December 25,2006 This application for Sundry approval for Kuparuk well 3K-22A is for inspection and possible ,/ repair ofthe surface casing. The well is an injector, drilled in completed in 1997 and side tracked in 2001. This well is a single casing well on a drill site that has several wells with known surface casing leaks. This request is for approval to excavate, inspect and repair if needed the casing on 3K-22A before any leaks occur. With approval, inspection and repair of the surface casing will require the following general steps: 1. 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. Q A/QC the repair welds and MIT - IA to verify integrity 8. Install anti-corrosion coating on exposed surface casing. 9. }>atch the conductor and topoffthe conductor void with cement and waterproof sealant. 10. Backfill gravel around the wellhead. 11. Remove plugs and return the well to injection. 12. Submit 10-404 report of repair operations to AOGCC. • • WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. . To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. ∎-% Attn: Robert A. Richey, 130 West International Airport Road V "∎c--C) Z.- ' '%\ wvs Suite C irri■kozsZ Anchorage, AK 99518 Fax (907) 245.8951 1) 1 Report 3 MTI 11 -Oct-06 2) 1 Report 3R - 25 MTT y - Uct - uti 0- 3) Co 4) it A y®!)) NOV 20rA 5) 6) 7) GENE ,, /��,` 1.!?..i ! I'Ji O Signed : r Date : ` Print Name: l ' A rt -li IA P, 1 A rt.litud9 J PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RI) SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 - 8951 Fax: (907)245 - 88952 E -MAIL WEBSITE .....,',7s'., D _PDSANC- 2006\Z_ Word\ Dishibubon\ Transmi ttal_SheetsTransnut_Origmal.doc • • I tip Memory Magnetic Thickness Tool ► Log Results Summary I Company: ConocoPhillips Alaska, Inc. Well: 3K -22 Log Date: October 11, 2006 Field: Kuparuk Log No.: 8057 State: Alaska I Run No.: 1 API No.: 50-029-22759-00 Pipet Desc.: 4.5" 12.6 lb L-80 NSCT Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 190 Ft. (MD) I Pipe2 Desc.: 7.625" 29.7 lb L -80 Top Log Intvl.: Surface Pipe2 Use: Surface Casing Bot. Log Intvl.: 190 Ft. (MD) Pipe3 Desc.: 16" 62.50 lb H-40 Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) I Inspection Type : Assess External Corrosive Damage (Metal Loss) to Surface Casing. I COMMENTS : This MTT data is tied into the Mandrel Hanger @ 0' Depth. I This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 4.5" tubing and 7.625" surface casing, with some influence from the 16" conductor pipe. I Due to the concentric pipe strings in the log interval, the MTT response is qualitative — indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (70'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, I which include influences from the 4.5" tubing, 7.625" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS : The MTT log results cover the interval from surface to 190'. A log plot of the entire pass, plus a detailed 1 section of any interval showing damage is included in this report. The Delta Metal Thickness ( %) curve in I these plots refers to total metal surrounding the MTT tool. A maximum of 26% circumferential metal loss is recorded below the Mandrel Hanger between 0' - 1'. A 2% circumferential metal loss is recorded in the interval between 5' - 7'. I The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 4.5 ", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" surface casing, the percent metal loss from that pipe alone is probably higher than the I numbers expressed. Some of the metal loss indicated could be from either the 4.5" tubing or 16" conductor. I I Field Engineer R. Richey Analyst: M. Tahtouh & J. Burton ID u Is,U ,�MI Wir ,I,JR e 1;7: e :::t . . .,) : ._. - . • - , r 659-231e NOV 0 3 2006 I Alaska Oil & Gas Cons. Commission u _ 1 q --- O ( o ( o Anchorage I Magnetic Thickness Toll Pog (8Hz Pass) I PRoAcrtvE Magmas Tic SERVICES Inc. Database File: d: \warriondata\ 3k-22 \3k-22. db Dataset Pathname: 8Hz.1 I Presentation Format: 24SCAL-1 Dataset Creation: Thu Oct 12 07:09:24 2006 by Ca lc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1:150 I -50 Delta Metal Thickness (%) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ft/min) -200 -6.4 MTTP12 (rad) 3.6 1 — - - - - -- _ - - 77r= - -_,;, _ ._.._ iWiralT=g— milliml-....---_---,-------- • 41 IN _20 MEMMEMEMMEMNEWEEMMEM MEM WIIIIMINIBINLINIEMININ MI 4.1r-iummumalmol*: ; 1 -- -- — . 111 11--- -*-."7.-7 7 4MMEMMEM=MMPIO■ - - . . MMEM•MMI7 - — '- : .... ,mam. ----7 1 m _■. — - — --._ - — — _ _ _ _ , _ _ 10 -- - -- 7 ----. ' Ili --- - =10== --- 7 1===-_,■■■ . — • Tree IMmur===. ____ ______ ,________ iimm■•.----- _ _ ____ __ _ InnilliriMIN Hanger- ° 1.: a--,,.-.7-mm IN • 26% MetalwIII Loss w 1 , . ar 7.62515con C ollar M Pup Jt. 2% Metal Loss -1--"-Wholih-elM WillrtinnialrAlrAMMI AIEWINElieriMMFAM nuwmwommomamiummammm • • 10 MMWMILIMMIUMMWEINIMMMIIIMUM mmermwmmirmirmniminnimilmm MANWAMMLINFaillriffkgMUMMMHM John imitommara•mium I 20 mmwimwmilvAwiwim cmummiumsnm MMWWWMUWMMMEM•IM•NM• MMWMWWAWARMftMILAMUMMUHM I , Line Speed MMWMWMINKJOAMMUMIUMMINOM MIMAINEMMIVMMVMMIMIMIWRINM IIIMMIMMEMWMMMMOMUOMLIMM 30 mrammmmtmcommwmunmiewm • _ 4 " Colla •= IMffallIP illED1111 IMAM E ki• ME MINE-4 MI • IIIMINMWMMWMMIEMMIIIMUMNFIM 1 MMWMIWAMMMMAWMUMNIMINVIM • 4o ip-mwmwmowimmommmunim maiiirmilmmmalimelmnummwm MAMMWMFINIMMWMUMWOMMUM WOWOMMUWWMWOMMIPLAMILIMM I 7.625" Collar WQINgtMCIPIWMMIL 45 . MAMMWMMWMOMMNIIMUMMIVIM mAlamwminammegmunmm&-im 1 ill " EMIRS, WMPUMHUM I w.moemmwmAlw=Nmnualwam. . w mmwommmiromwm,Amirommn. mFA..mitawmirmiram • 5" Collar morrraimowiiriE-J•• im.:EVw..immoviimr7 - ilniritimmraimm WMWMWMMIEMMMMIAMMIMMUM MIOAIMMWMMMWMWMNIWIMMMMIIII 45 . MMWMWMAIMWMPIMMMUMMMFAM • Joint 3 WallEMMIVIIIIPMMF-3MMMMM IrLaimillimmummilmml iiiimvmnwasimmamrammollim I _ - 2 I M `4IE1WMII` :TII�IM Bottom of 16" u �L r W'�I� IN� � 1 INIFAI .irl1,�RINAIMiMIAMM E1I111I;I1111111111111•IE:l1IIIIIIME 1 b I�IIELIL� &IIL - 7.625° Collar 90 lMIili!lli NI ANIM Iriii_aillFlIFIIIlIMILEI MIIF 1 .5" Collar �III1lill9ltiillllllijllE�Itl F 1aa IIIMMIMMIMEN/1111111:11 1 4.5" LIHtIitIiIIIIIiiiItI Joint 4 .IEII.....iE.IE� 1 WIMEIMERMIlltilllillltillintilliMMIER SIIEEIE #EE![uN4ItaIIIAMME. RIMU MUE1•111•1IE11ItII?llll1111 I . E�IEIIEIEEiEiNl lEgI'a�E�iEl1WRIM i 120 IIEMILINININIIMINMLIIMMIKAILIIIIILINIV rwrorlriaril iEiaral rawa Iirii.riiirlimraE;riras 1Ma ms c-A 1 , .5" Collar IMEMIlEMILIIEIIIII!lISEMEE EIIEII MINIMPII!]IEIIII11MlE 1MME 130 I'ItIIE��Ifr 1E1rliilIE�It�IIE� . I IlM4I lI'!!alliinpilll: 1 • - 7.625" Collar E EMEEOEE EMIME - ZIfWE - 4.5" 11!lMIraI E.INI�iIin1l�I Joint 5 IMI IIiNI 1 40 illEilIER11•111lE�11MME IIIMII 1 iiriiiiiiiiiuriiumiiiii 1 Fi.EEiIEiI�itll[hitIli1Il 150 wismi!quammaiilo!!li!!i7 - c r - i 1 EiC mE' m war i:aCrErC _ IniEmo WiiiiFatwimMFAINE211 GlErii 1 4.5" Collar IMIN- 111111ii1111iIENIlIlt1ilE1IM Ili1IEEI111111IEMEMI III'.IE1II111I=E 160 NCI ;1l�lE�llt'�EIIEIIIE�IIE1IEE tiIE4IiEiIEaltiI EMIRlE!lELIEU I 1111111111113111111111111141EMEMMEA11111E111111 4 5 " 111111E111111111111/1MinalMilMIER1111111111111111111 Joint IIMIILMEMININ1111111111F1111.4111111111MMIM 1 70 MtilltOMMEINIE1EI��IIEMI I 1 11111111E-1IMEI ICI11Il11MIMI 3If E I IM!sllllIEI lM iIrA! 7 .625" Collar !'ibi- a"- ZIM jr�iF= 1 ----7--- IllinlIilnliggl fltiliaillal i ll 1 E��lIIE I IIIl��EelE liEMLIII I " 4 -------- IrANIMIIMIELIWanillriariliOWAIMEWAINFRI 4.5" IIIII:iIIIEI l Collar IIIIi1!`I 1 Fri 01ldItilll_IIII1-1I11ffiII 190 E -1111 —End of Log - E��W SyMfGaNi��E�E�i�! 1 _50 Delta Metal Thickness ( %) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ft/min) -200 -6.4 MTTP12 (rad) 3.6 1 1 1 I. ., _ • 1 Magnetic Thickness To•og (8Hz Pass) I PRoAcatvt DIAgnoscic SE•V10E3, Inc. Database File: d:lwarriorldata13k- 221top metal loss13k -22.db Dataset Pathname: 8Hz.1 I Presentation Format: 24SCAL -1 Dataset Creation: Thu Oct 12 07:09:24 2006 by Cale Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1:60 I -50 Delta Metal Thickness ( %) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ft/min) -200 -6.4 MTTP12 (rad) 3.6 -.. - ! i t - - t — . I I _.. 1 �••r. =tea - �i`=�� ∎r 1 1 I 1 . -- ..:- - _ „....M...,,,,,......=- : - ' - - II■ � i ' arc_. I 1 � � i 4— Line Speed M��— _ -- = — - -- , _ - Tree _ -_ Hanger- 0 1ii � � 26% Metal P Jt. — i LOSS P i= _ �-.� . �� '� 4.5' Collar - E -1 I r 1 elf al Ir ' i 7.625 Collar 111E111111111111-411111111111Fill iiiiii 2 °1° Metal Loss iiflhIHiUuIiuiItiI 11 __11111 10 I1iiHiiiItiAIUUIU. 1 11__1.1111 1IiIHflPiIi 11 45” llllll.illlllll Ir ",,,, Joint 1 I 1HhIIiiUIi1IUHI 11__11111 11 1 1 /1mmmmmo" 1 1 1111111 20 1111=1L1111FiUiiii1H111 r 11__11111 1 1 11 111111 1111 iI11H1HH1 2■ ■ ■■ ■MEMENFAri -50 Delta Metal Thickness ( %) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ft/min) -200 -6.4 MTTP12 (rad) 3.6 1 1'• • • 014 ConocoPhillips Alaska, Inc_ KRU 3K -22 '3K-22 API: 500292275900 Well Type: INJ Angle @ TS: 70 deq @ 8247 SSSV Type: NIPPLE Orig 5/5/1997 Angle @ TD: 93 deg @ 11180 I NIP (524-525, Completion: OD:4.500) Annular Fluid: Last W /O: 3/18/2001 Rev Reason: Pull Plug Reference Lop: Ref Log Date: Last Update: 4/21/2003 Last Tag: 11904 (junk) TO 11180 ftKB Last Tag Date: 7/15/1999 _ Max Hole Angle: 94 deq @ 10788 I Casing String - ALL Description Size Top Bottom ND Wt Grade Thread CONDUCTOR 16 000 0 121 121 62.50 H -40 SURFACE 7.625 0 4887 4091 29.70 L -80 I SLEEVE LINER 4.500 4677 11175 _ 6661 12.60 L -80 NSCT (46274628' 1 1 Tubing String - TUBING OD 4.500) Size Top Bottom ND Wt Grade Thread 4.500 0 4677 3925 12.60 L - 80 _ NSCT Perforations Summary I Interval ND Zone Status Ft SPF Date Type Comment TUBING 9195 - 9450 6637 - 6651 A -3 255 4 5/5/1997 IPERF SWS 2 7/8" HSD; 60 deg. (04677, phasing OD:4.500, 9675 - 9826 6656 - 6651 151 4 5/5/1997 IPERF SWS 2 7/8" HSD; 60 deg. 103.833) PKR phasing 237 4 5/5/1997 IPERF I PKR • 9933 - 10170 6652 - 6669 SWS 2 7/8" HSD; 60 deg. (4671-0678 phasing 10345 - 10470 6684 6688 A -2 125 6 5/5/1997 IPERF SWS 2 7/8" HSD; 60 deg. 00:6.750) phasing 10685 - 10855 6687 - 6677 170 6 5/5/1997 IPERF SWS 2 7/8" HSD; 60 deg. I phasing 10915 - 10930 6674 - 6673 15 6 5/5/1997 IPERF SWS 2 7/8" HSD; 60 deg. phasing 10960 - 11060 6671 - 6667 100 6 5/5/1997 IPERF SWS 2 7/8" HSD; 60 deg. LINER I phasing (4OD:4.175, Other (dugs, equip., etc. - JEWELRY 00:4.500, Depth ND Type Description ID Wt12.60) 524 523 NIP Camco 'DB' Nipple NO GO 3.813 4627 3885 SLEEVE Camco'CM' Sliding Sleeve w /Camco'X' Selective Profile 3.813 I 4677 3925 PKR Baker'SABLM/ZXP' 3.812 9101 6630 NIP Camco'DB' Nipple NO GO 3.750 NIP 11075 6666 FILL Fill following CTDU millout, from collapse of walls 3/18/01 3.000 (9101 -9102 11111 6664 COLLAR BAKER DOUBLE FLOAT VALVE COLLAR 3/18/01 3.000 00:3.833) 11175 6661 SHOE BAKER 4.5" V -TYPE FLOAT SHOE 3/18/01 3.000 I General Notes Date Note 3/18/2001 CTDU milled down to 11175, but fill collapsed into hole, to PBTD. Pert —' — PBTD 811075' at bottom of milled out shoe (91959450) — 12/9/2001 _WAIVERED WELL - monobore completion, water injection only (9675 - 9826) - - °— 1 Perf --- (9933-10170) -- • ---° I Perf (1034610470) _ _. -- Pelf . -- ' (1068610655) Peri (10915-10930) —_ II Pert -. - (10960 - 11060) -- . --- • • • • FILL 1 (11075-11175, • • • • 00:4.500) • ®AAs78:l~~d'~~d®~ ~® -7~~®~ • FRA/VK H, MURKOWSKI, GOI/ERAIOR 333 W. T" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907} 276-7542 ADMINISTRATIVE APPROVAL AI® 2B.®13 Mr. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99~ 10-0360 RE: Kuparuk River Unit 3K-22A (200-026) Request for Administrative Approval Dear Mr. Dethlefs: ~~d1~~ JAN ~ ~ 2008 On ~1ay 28, 2006 ConocoPhillips Alaska, Inc ("CPAI") requested an administrative approval under Rule 9 of Area Injection Order ("AIO") 2B to allow continued water injection in Kuparuk River Unit ('`KRU") well 3K-22A. The Alaska Oil and Gas Conservation Commission .("Commission") GRANTS CPAI's request for WATER ONLY service, as detailed below. As constructed, KRt,1 3K-22A does not meet the requirements of 20 AAC 25.412 (b) for an injection well which is required to be equipped with a packer set not more than 200' measured depth ("md") above the top of the perforations. The purpose of this requirement is to ensure that the injection string can be monitored throughout its length for possible leakage. Some 4500' of this wellbore cannot be monitored. Where fresh water is not affected, 20 AAC 25.450 gives the Commission authority to approve less stringent well construction and integrity requirements. For wells similarly constructed, the Commission has exercised this discretionary- authority and approved injection operations with the fluid limited to water only. CPAI has provided pressure test information, dated April ~, 2005, using water that demonstrates that the injection string (combination of tubing and liner) and the surface casing (the 7-5/8" casing above the packer) do have integrity. Accordingly, the Commission believes that the well's condition will not result in an increased risk of movement of fluids outside the injection zone. Per Rule 9 of Area Injection Order 2B, the Commission hereby grants CPAI's April 27, 2006 request to continue injection in well KRU 3K-22A on the following conditions: 1. Injection is limited to WATER ONLY; Administrative Approval AIO 2B.013 June 27, 2006 Page2of2 2. CPAI shall monitor and record tubing, inner annulus pressures and injection rate daily; 3. CPAI shall submit to the Commission a monthly report of well pressures and injection rates including any pressure bleed events; 4. CPAI shall perform a mechanical integrity test of the tubing ("NIIT-T") every 2 years with a plug set at or below 8200' and (--600' tvd) to demonstrate continued integrity of the injection string, ~. CPAI shall perform a mechanical integrity test of the inner annulus ("MIT- I4") every 2 years to demonstrate continued integrity of production casing; 6. CPAI shall immediately shut in the well and notify the Commission if there is any change in the well's mechanical condition; and 7. After well shut in due to a change in the well's mechanical condition, Commission approval shall be required to restart injection. 8. For administrative purposes, the VIIT anniversary date is April 5, 200. As provided in A5 3I.0~.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~mmission decision to Superior Court unless rehearing has been requested. i~~ ! i Alaska and dated June 27, 2006. ~~ 'r ~ ,.; `'^ i f °\ K. Daniel T. S~eamount, Jr issioner Cathy P/. Foerster Commissioner ~, ~~~' 3~~~ / ,~. . ,.~. x v ~~~ V ~. / =.r ~, _ ' ~c~~_ "f 'r ,> .*" ~~ m `~} ~ ~. Maunder, Thomas E (DOA) From: Dethlefs, Jerry C [ Jerry .C.Dethlefs @conocophillips.comj Sent: Friday, September 23, 2005 4:41 PM To: Maunder, Thomas E (DOA) Cc: 'NSK Problem Well Supv' Subject: RE: Monobore Injection Wells Tom: To my knowledge you are correct. Since we recently "discovered" 2M -09A, I cannot guarantee there are not other anomalous wells out there we do not know about. But your list looks complete for the wells we do know about. Should we come across another in this situation you will be the first to know. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659 -7043 ��. ,. MA" 18 `ZU14 Original Message From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, September 23, 2005 9:22 AM To: NSK Problem Well Supv Cc: Jim Regg Subject: Monobore Injection Wells Jerry, et al: We are checking our records and wanted to confirm the wells that are monobores. There are various wells out there that have had the name "monobore" attached to them. For this message, monobore means a well that does not have a separate production casing set proximate to the injection horizon and the packer is set a significant distance above the zone. The first 4 wells on the list have the packers set in the surface casing. The w s o ur "list" are: 0— -4z)( 3k 3 3 aOC1- ©3-Cv 3-19 �J'] 3Q Q -21 3R -25 and possibly 2M -09A 3H -10B would also be on the list, but it is a producer never having been converted. Thanks in advance for your assistance. Tom Maunder, PE AOGCC 1 MEMORANDUM State of Alaska TO: ') Jim Regg ~~ "/27'Ù,> P.I. Supervisor lot. f( Alaska Oil and Gas Conservation Commis~: -) DATE: Tuesday, April 12, 2005 ' SUBJECT: Mechanical Integrity Tests CONOCOPIDLLIPS ALASKA INC 3K-22A KUPARUK RIV UNIT 3K-22A 'JIJ.... .., ·.e·.".·.'~(),J, - ~~ ' .~;:' ~ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv, 'f8a- Comm Well Name: KUPARUK RlV UNIT 3K-22A Insp Num: mitJJ050407135241 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-22759-01-00 Permit Number: 200-026-0 Inspector Name: Jeff Jones Inspection Date: 4/5/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-22A Type Inj. S TVD 3925 IA 0 2480 2360 2330 P.T. 2000260 TypeTest 8PT Test psi 981.25 OA Interval REQVAR P/F P Tubing 1740 1910 1920 1930 Notes: This waivered mono bore well is operated under the provision that an MIT be performed on a 2 year cycle. The well was not injecting during the test and the operator indicated that a bullplugged eclipse packer was set at 8300' MD to facilitate the test. 3 BBLS of diesel was pumped into the annulus and although the tubing pressure appeared to be increasing slightly, this well meets the AOGCC criteria for a succesful MIT A. ,AJ\J.4 -:I:¡\r SCPlNNED WLAY 3 1 20U5 Tuesday, April 12,2005 Page I of 1 MEMORANDUM TO: Jim Regg ~'-GtÍ11 P.I. Supervisor --.J {¡ 4 ~ 'l7to6 State of Alaska Alaska Oil and Gas Conservation Comm, )1 DATE: Tuesday, April 12, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-22A KUPARUK RIV UNIT 3K-22A -' o'W ~fJJ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv...:3?¡2... Comm Well Name: KUPARUK RIV UNIT 3K-22A Insp Num: mitJJ050407142154 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-22759-01-00 Permit Number: 200-026-0 Inspector Name: Jeff Jones Inspection Date: 4/5/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-22A Type Inj. s TVD 3925 IA 90 170 180 180 P.T. 2000260 TypeTest 8PT Test psi 981.25 OA Interval REQVAR P/F P Tubing 1730 3000 2950 2930 Notes: This waivered mono bore well is operated under the provision that an MIT be performed on a 2 year cycle. The well was not injecting during the test and the operator indicated that a bull plugged eclipse packer was set at 8300' MD to facilitate the test. 1 BBL of diesel was pumped into the tubing and this well meets the AOGCC criteria for a succesful MITT. It·t:]:: - 'I ¿~ -\ '2 a C'5 ~¡!t:n VIii i\~'9 t - SCAN;"r.;.;.v l~lM '"- Tuesday, April 12, 2005 Page 1 of 1 ~ ConocoPhillí¡:. . . NIP (524-525, 00:4.500) SLEEVE (4627-4628. 00:.\.5001 TUBING ()...16 77 . 00:.\.500, 10'3833, PKR (4677 ..\.673. 00:6. ì501 LINER (4677-11175 00:4 500 Wt:12601 r·Jlp (9101-9102. 00:38331 P~rf (9195-~50 P~rf (9675-98261 Perl (9933-101701 P<;:rf (10345-10.\701 P<;:rf (10685-108551 Perf (10915-10930) Perf (1 09€0-11 060) FILL (11075-11175. 00:4.500) -~!~,;~- I .~ u - -. - . . . . . ~.~ :t Àlaska, Inc. 3K~22 API: 500292275900 SSSV Type: NIPPLE Annular Fluid: Reference Log: Last Tag: 11904 Gunk) Last Tag Date: 7/15/1999 Casihg;St~irig,,;.'ALL Description CONDUCTOR SURFACE LINER Tijb,il1~.·String.';;TUBI NG Size I Top 4.500 0 ·PènoriåtiòÏ1sSlimmårý Interval TVD 9195-9450 6637-6651 9675 - 9826 6656 - 6651 9933 -10170 6652 - 6669 10345 -10470 6684 - 6688 10685 - 10855 6687 - 6677 10915-10930 6674 - 6673 10960 - 11060 6671 - 6667 KRU Well Type: INJ Orig 5/5/1997 Completion: Last W/O: 3/18/2001 Ref Log Date: TO: 11180 ftKB Max Hole Angle: 94 deg @ 10788 Size 16.000 7.625 4.500 Top o o 4677 Bottom 121 4887 11175 3K-22 Angle @ TS: 70 deg @ 8247 Angle @ TO: 93 deg @ 11180 Rev Reason: Pull Plug Last Update: 4/21/2003 TVD 121 4091 6661 Wt 62.50 29.70 12.60 Grade H-40 L-80 L-80 Thread NSCT Status Ft SPF Date Type Comment 255 4 5/5/1997 IPERF SWS 27/8" HSD; 60 deg. phasing 151 4 5/5/1997 IPERF SWS 27/8" HSD; 60 deg. phasing 237 4 5/5/1997 IPERF SWS 27/8" HSD; 60 deg. phasing 125 6 5/5/1997 IPERF SWS 27/8" HSD; 60 deg. phasing 170 6 5/5/1997 IPERF SWS 27/8" HSD; 60 deg. phasing 15 6 5/5/1997 IPERF SWS 27/8" HSD; 60 deg. phasing 100 6 5/5/1997 ¡PERF SWS 27/8" HSD; 60 deg. phasing Zone A-3 A-2 Other l,lugs, equip., etc.' - JEWELRY Depth TVD Type 524 523 NIP 4627 3885 SLEEVE 4677 3925 PKR 9101 6630 NIP 11075 6666 FILL 11111 6664 COLLAR 11175 6661 SHOE General··' Notes Date Note 3/18/2001 CTDU milled down to 11175, but fill collapsed into hole, to PBTD. PBTD @11075' at bottom of milled out shoe 12/9/2001 WAIVERED WELL - monobore completion, water injection only Description Camco 'DB' Nipple NO GO Camco 'CM' Sliding Sleeve w/ Camco 'X' Selective Profile Baker 'SABLM/ZXP' Camco 'DB' Nipple NO GO Fill following CTDU millout, from collapse of walls 3/18/01 BAKER DOUBLE FLOAT VALVE COLLAR 3/18/01 BAKER 4.5" V-TYPE FLOAT SHOE 3/18/01 ID 3.813 3.813 3.812 3.750 3.000 3.000 3.000 F: \LaserFiche\CvrPgs _ Inserts\Microfilm _Marker .doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE UI¢ File Review Date: Subject: PTD #: Orders: Reviewers: Initiating Action: October 14, 2003 ConocoPhillips KRU Well 3K-22A (Water Injector) 200-026 Sundry #: 303-306 CO 173 originally and most recently CO 432 B AIO 2B and prior versions Tom Maunder, P.E. Application for Variance Review Summary 1. According to the available records, 3K-22 was drilled as a "monobore" injector and was completed as a water injection well in February 1986. This well was one of 5 constructed by ARCO at that time. The well design had surface casing as usual and then a single tubing sized string that was cemented in place through the normal Kuparuk interval and included a packer that was set near the bottom of the surface casing. 2. After these wells were constructed, there were several documents exchanged wherein this construction practice was discouraged and that the 5 existing wells could be placed in service, but were limited to WATER ONLY with a 2 year MIT cycle. 3. In early 2000, ARCO proposed to drillout the 4-1/2" shoe using coil tubing and gain access to additional interval. This operation was not successful, although wellbore was drilled heaving shales collapsed the open hole section and operations were halted. 4. On July 16, 2002, the Commission administratively abandoned 3K-22 due to the drilling of new hole with the resulting well name being 3K-22A. 5. Phillips submitted a sundry (301-172) requesting to keep 3K-22 in water only service on June 25, 2001, however due to the unsuccessful attempt at drillout the well was shut in pending determination of new plans. The sundry was returned to Phillips. 6. Prior to determination to administratively abandon the well, ConocoPhillips did obtain email approval to keep the well in WATER ONLY service and has been operating the well according to the guidelines established for injection wells with known communication. The well most recently passed a MITT on April 1, 2003. 7. Chronological Review of files revealed: a. CO 173 originally (May 6, 1981), most recent order CO 432 B (December 12, 2002) b. AEO: EPA exempted all aquifers for the Kuparuk River oil and gas field [40 CFR 147.102(b)(3)]. c. AIO 2 (June 6, 1986) - Class II underground injection authorized within the KRU. The well is located within the authorized area. d. Blair assessed MIT II December 12, 1997. "MI indicated" was determined. Technical Evaluation of Request - Submitted monitoring records indicate that ConocoPhillips has been operating the well within the guidelines for established for operating injection wells constructed as "monobores". There appears to have been a paper work "glitch" regarding the originally submitted sundry notice. Approving this 403 application will not promote waste or the movement of water outside of the intended injection zones. This is no fresh water to protect. Recommendation File Review indicates compliance with provisions of 20 AAC 25, CO, and AIO (as superceeded). Approval of ConocoPhillips' request is recommended subject to following conditions: a. The well may remain in WATER ONLY service. b. Submit monthly report of daily well pressures (T/I/O) and injection rate. c. If monitoring data indicates any further integrity loss, the Commission must be notified and a new action plan determined. d. If ConocoPhillips believes that a determined integrity loss could result in fluids being injected into strata other than the Kuparuk,formation, injection must cease and the well secured. e. Perform tubing integrity test MITT every 2 years.. Due to the configuration of the downhole equipment, ConocoPhillips should have the option of how they set the needed deep plug. The proposed plug depth is below the determined TOC. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 41' 8. Property Designation: Kuparuk River Unit 11. Total depth MD (ft): Total Depth TVD (ft): 1 1 180' 6661' Casing Length CONDUCTOR 121' SURFACE 4887' LINER 6498' Perf Depth MD:9195-9450', 9675-9826', 9933-10170' 10345-10470', 10685-10855', 10915-10930', 10960-11060' Packers and SSSV Type: pkr= BAKER 'SABLM/ZXP' SSSV= NIP Suspend r~ Operation Shutdown Repair well ~ Plug Perforations E~] Pull Tubing E] Perforate New Pool 4. Current Well Class: Development Stratigraphic Perforate E~ Variance [~1 Annular Disp. r--~ Stimulate [--1 Time Extension F-~ Other Re-enter Suspended Well J 5. Permit to Drill Number: Exploratory [~ I 1.1.1.1.1.1.1.1.1.1~~ Service [-~ I 6. APl Number: I 9 . Well Name an~ Number: 10. Field/Pool(s): Kuparuk Oil Pool 4-1/2" PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 11 075 6666 Size MD TVD 16" 121' 121 7-5/8" 4887' 4091 6661 11175' Junk (measured): Burst Collapse Perf Depth TVD:6637'-6651', 6656-6651', 6652-6669' Tubing Size: Tubing Grade: 6684'-6688', 6687'-6677', 6674'-6673', 6671'-6667' 4-1/2" ,' L-80 Packers and SSSV MD (ft) pkr= 4677' SSSV= 524' 12. Attachments: Description Summary of Proposal [~ Detailed Operations Program E] BOP Sketch E~ 14. Estimated Date for Commencing Operations: June 11, 2001 16. Verbal Approval: Date: 6/11/03 T Maunder 13. Well Class after proposed work: Exploratory r'-] Developm~ni''r-] 15. Well Status after proposed work: Oil F1 Gas [] Plugged ["-] WAG [~ GINJ r'~ WINJ E~ 17. I hereby certify that the foregoing is true and correct to the best of m.y..Jr, frbwledge. Printed Name MJ Loveland _ // ~ Signature ~'~'/~ ~,~.,,,,,~/~ /~ '/" Commission Use Only Tubing MD (ft): . 4677' Conditions of approval: Notify Commission so that a representative may witness ServiCe:,.,' F~I Abandoned F"I: WDSPL E~] contact: Title: Phone 659-7224 MJ Loveland/Nina Woods Problem Well Supervisor Date ~/~//~.~///,~ _~ ISundry Number: .-.~3- Plug Integrity E~ BOP Test E] Mechanical Integrity Test Other: Location Clearance,,....,~ .................. Subsequent Form Required: t - '"~ v,, , ~. ~,"~ t -- ' ..... ~. ~t,~6 ~ BY ORDER OF Approved by: ~ COMMISSIONER THE COMMISSION Date: F°rm 10'4°3Re~~L ¢ ,O !GINAL SUBMIT IN DUPLIOATE Phillips Alaska, Inc. Kuparuk Well 3K-22 SUNDRY NOTICE 10-403 VARIANCE REQUEST 10/04/03 The purpose of this Sundry Notice variance request is to clarify Mechanical Integrity Test (MIT) requirements for the 3K-22 monobore completion. The requirements were determined in a meeting between the AOGCC (Tom Maunder) and Phillips Alaska (Jerry Dethlefs) on June 11, 1. These terms modify and supersede the conditions sent in a letter to ARCO Alaska, Inc., ~r0o0m the AOGCC (Blair Wondzell)dated May 2, 1997. _.... ~\~,o ca..,%~xc.s~,,.-h ~:,o~'~.~"~'c~ Kupamk well 3K-22 ~s a monobore injection well classifie:'I--2 a "failed MIT due to Ul¢ %-~ construction of the wellbore (i.e., the packer is not set within 200' of the perforations). Extensive '-' portions of the casing/tubing cannot be monitored from the surface so communication or leak problems may go undetected. The lower section of the well is horizontal and the existing landing nipple above the Oerforations is in the horizontal section. The well passed an AOGCC witnessed MITT / MITIA 02/03/01. A coiled tubing bridge plug was set in the tubing @ 9091' md. Subsequently, on 4/1/03 the well passed an additional AOGCC witnessed MITT/M1TIA using an Eline set retrievable plug @ 8315' md. ACTION PLAN From this date forward 3K-22 will be subject to the following requirements: 1. The well will be used for water injection only (no gas injection is allowed); 2. Perform an MIT-tubing every 2-years subject to standard test criteria ( 0.25 x tvd @ packer or 1500 psi minimum, whichever is higher); 3. The MIT-tubing must be tested against a tubing plug set at or deeper than 8200' md. Any type bridge plug designed for this service is acceptable. A second option is to pump a plug down to the existing landing nipple @ 9101' md for the test (Phillips' option). 4. Perform an MIT-IA to a minimum of 1500 psi to the existing packer @ 4677' md. 5. Submit monthly reports of daily tubing & IA pressures and injection volumes; 6. Shut-in the well and notify the AOGCC should MIT's or injection rates and pressures indicate further problems; 7. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification. NSK Problem Well Supervisor 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 - 3K 04/01/03 APo - Sauva~leau Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. WeH13K'22 I Typelnj I PWI ] T.V.D.I 6540 I Tubi~gl 5001 30251 29851 29701 ~.t~vaTl 0 I P'T-D-12000260 I TYPeTestl P I Test psiI 3000 { Casincj I °1' °l 01 01 P/F Notes: MITT to WRP set @ 8315' MD (6540 TVD) WeU13K-22 I Typel.jl PWII T.V.D. I 3925 Im~bi.gl 6001 7501 7501 7S011ntervalI O P.T.D.12000260 I.TypemestI P 'JTestpsiI 1600 I Casingl 01 16501 1550{15451 P/F I P Notes: MITIA to existing packer (monobore completion) I P.T.D.J Notes: I Typelnj I I T.V.D-I ITubin~ll I I I Ilnterv~J'l Type Test Testpsi l1506ICasin~l'l I I I I P/F ',"1 I P.T.D.I ,, , Notes: P'T'D'I Notes: I TYPe',nil I Type TestI I Test psiI 1500 I Casin~l I I , I I I P/F I ' T.V.D. 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: O5/19/02 MIT KRU 3K-22 04-01-03.xls 4/28/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance _X Perforate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 3905' FNL, 4962' FEL, Sec. 35, T13N, R9E, UM At top of productive interval 576' FSL, 1649' FWL, Sec. 26, T13N, R9E, UM .At effective depth 1893' FNL, 2850' FEL, Sec. 26, T13N, R9E, UM 5. Type of Well: Development _ Exploratory w Stratigraphic _ Service__X (asp's 529304, 6008366) (asp's 531378, 6015668) 6. Datum elevation (DF or KB feet) RKB 41 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3K-22 9. Permit number / approval number 197-O66 10. APl number 50-029-22759 11. Field / Pool Kuparuk Oil Pool 12. Present well condiUon summar Total depth: measured 11180 feet Plugs (measured) true vertical 6661 feet Effective depth: measured 11075 feet Junk (measured) true vertical 6666 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 129 sx AS ~ 121' 121' ,~URFACE 4887' 7-5/8' 393 sx ASLW, 410 sx CI G, 65 sx 4887' 4091' AS I LINER. 6498' 4-1/2" 6o0 sx C~ass G 11175' 6661' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 9195'-9450', 9675'-9826', 9933'-10170', 10345'-10470', 10685'-10855', 10915'-10930', 10960'-11060' 6637'-6651', 6656'-6651', 6652'-6669', 6684'-6688', 668T-6677', 6674'-667~, 6671'-6667' 4-1/2", 12.6#, L-80 Tbg @ 4677' MD. BAKER 'SABLM/ZXP' @ 4677' MD. CAMCO 'DB' NIPPLE NO GO @ 524' MD. 13. Attachments Description summary of proposal __~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation ~ 15. Status of well classification as: June 11, 2001 I 6/~.1/Ol Date approved ~ 16. If proposal was verbally approved Oil __ Tom Maundel Name of approver Service Gas ~ Water Iniector Suspended__ 17. I hemby/~, at the foregoing is true~-c~~o~ my knowledge. Signed ~'"/~ ~ ~,-.---~'---~ .,) Title: Problem Well Supervisor Jera. Ja' C. Dethlefs .. (__._ .~ FOR COMMISSION USE ONLY Questions? Call Jerry Dethlefs 659-7224 Prepared 1~/ Sharon Ails u~-Drake 263-4612 Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance __ Mechanical Integrity Test_ Subsequent form required 10- Approved b~.. ,,order of the Commission Commissioner Approval no. Date Form 10-403 Rev 06/15/88 · Return to: Problem Well Supervisor, NSK-69 SUBMIT IN TRIPLICATE Phillips Alaska, Inc. Kuparuk Well 3K-22 SUNDRY NOTICE 10-403 VARIANCE REQUEST 06/23/01 The purpose of this Sundry Notice variance request is to clarify Mechanical Integrity Test (MIT) requirements for the 3K-22 monobore completion. The requirements were determined in a meeting between the AOGCC (Tom Maunder) and Phillips Alaska (Jerry Dethlefs) on June 11, 2001. These terms modify and supersede the conditions sent in a letter to ARCO Alaska, Inc., from the AOGCC (Blair Wondzell) dated May 2, 1997. Kuparuk well 3K-22 is a monobore injection well classified as a "failed MIT" due to the construction of the wellbore (i.e., the packer is not set within 200' of the perforations). Extensive portions of the casing/tubing cannot be monitored from the surface so communication or leak problems may go undetected. The lower section of the well is horizontal and the existing landing nipple above the perforations is in the horizontal section. The well passed an AOGCC witnessed MITT / MITIA 02/03/01. A coiled tubing bridge plug was set in the tubing @ 9091' md. ACTION PLAN From this date forward 3K-22 will be subject to the following requirements: 1. The well will be used for water injection only (no gas injection is allowed); 2. Perform an MiT-tubing every 2-years subject to standard test criteria ( 0.25 x tvd @ packer or 1500 psi minimum, whichever is higher); 3. 'The MIT-tubing must be tested against a tubing plug set at or deeper than 8200' md. Any type bridge plug designed for this service is acceptable. A second option is to pump a plug down to the existing landing nipple @ 9101' md for the test (Phillips' option). 4. Perform an MIT-IA to a minimum of 1500 psi to the existing packer @ 4677' md. 5. Submit monthly reports of daily tubing & IA pressures and injection volumes; 6. Shut-in the well and notify the AOGCC should MIT's or injection rates and pressures indicate further problems; 7. Workover and/or repair the well prior to gas injection consideration with apPropriate AOGCC notification. NSK Problem Well Supervisor 12/11/00 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY NIP (524-525, OD.4 500) TUBING (0.4677, O1~.4.500, 1~.3.833) (46274628, OI3:.4.500) (0-4887, · 00:7.625, W~29.70) (46774678, OD:6.750) (4677-11175, 0D:4.500, WC12.60) NIP (9101-9102, 0D:3.833) (9195-9450) (9675-9826) (9933-10170) (10345-10470) (106~5-10855) Ped (10915-10930) (lO96O-11o~o) COLLAR (11111-11112, 0D:3.810) FILL (11O75-11175, 0D:4.500) KRU 3K-22 3K722 AP1:'1500292275900 WellType: INJ "'/:--I:A;S:l"0d~@8247 SSSV Type: I NIPPLE Ori9 Completion:l 5/5/97 Angle @ TD: 93 dc=~ @ 11180 3/18/01 Rev Reason: [NORKOVER by Annular Ruld:I Last W/O:TD:i I ImO Reference Log: Ref Log Date:1 . Last Update: 3/29/01 Last Tag: 11904 (junk) Last Tag Date:17115/99 Max Hole Angle:111180 ttKB94 deg ~ 10788 :C~i~ii~ii:$~ii~"-':ALL~, ' '... .... ' ,:, :-,. ::,'::":'::~-:..'~ .'. :' i: .- DescriptiOn ..... 'size .... T~P' B0ff0'm" TVD I" "Wt" Grade i Thread CONDUCTOR 16.000 0 121 121 [62.50 H-40 SURFACE 7.625 0 4887 4091 [29.70 '.L-80 ' .. LINER I 4.500 I 4677 11175 6661 I 12.601 L-80 [ NSCT i.T_ubingS...t~..'n_g - TUBING Size ..... T-~p ..... ~'tt-~ .... T~D ..... I~i ' Grade':'" Thread .... 4.500 I 0 I 4677 I 3925 12.60I L-80 I 'NS. CT .Pe~ratiOns'SUmmary ". ' .... . : ~ . '. '." '..'".i: . .y":' '.":'; :.'"~;' . ': ' · . .... i~terval '?' TVD Zone Stat~s i~"~'~'F~ate Type .... -~)~m-~-~-~--nt --- ' 9195 - 9450 6637 - 6651 A-3 255 4 5/5/97 IPERF SWS 2 7/8" HSD; 60 deg. I phasing 9675 - 9826 6656 - 6651 151 4 5~5~97 IPERF SWS 2 7/8" HSD; 60 deg. I phasing 9933 - 10170 6652 - 6669 237 4 5/5/97 IPERF SWS 2 7/8" HSD; 60 deg. I ] I t ] I I I phasing 10345-10470 I 6684-6688I A-2 I J125 I 6 I 5/5/97 I IPERFJSWS27/8"HSD;60deg. _, phasing I I I I I I I Iphasing 10915-10930 I 6674-6673 I I I 15 I 6 I 5/5/97 I IPERF [SWS 2 7/8" HSD; 60 deg. 10960-11060 I 6671-6667 [ I I'001 6 [ 5/5197 IIPERFI!~!;12gTI8"HSD;60deg. ............... [ J ~. [ , I ! I ....... p~ ..... 9 ........... Depth I TVD I Type Description ID 524 I 523 I NIP l Camco 'DB' Nipple NO GO I 3.8i3 4627 3885 , SLEEVE Camco 'OM' Sliding Sleeve w/Oamco 'X' Selective Profile I 3,813 4677 [ 3925 I PKR [Baker'SABLM/ZXP' ' I 3.812 9101 I 6630 I NIP ICamco'DB'Nipple NOGO I 3.750 11075 I 6666 I FILL [Fill following CTDU millout, from collapse of walls 3/18/01 . I 3.000 11111 I 6664 I COLLAR [BAKER DOUBLE FLOAT VALVE COLLAR 3118/01 [ 3.000 11175 I 6661 SHOE IBAKER4.5" V-TYPE FLOAT SHOE 3/18/01 I 3.000 :G~h'i~l'::N~t'e~'..::!i:'; ..:..." .: '"' :."',::: ".' ':': ..... .:.':"' ..'. :" .'.,: '..': ';!'":~..i :":..;, !:.' ..,.' ",', :." '..:: ,'. ':.'i ."..': .:.:.'.' Date Note 3/18/01 CTDU milled down to 11175, but fill collapsed into hole, to PBTD. PBTD @11075' at bottom of milled out shoe MEMORANDUM TO: Randy Ruedrich Commissioner THRU: Jim Regg P.I Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 1,2003 SUBJECT: Mechanical Integrity Tests ConocoPhiliips 3K Pad 3K-22 KRU Kuparuk River Field NON- CONFIDENTIAL / Packer Depth Pretest Initial 15 Min. 30 Min. w~,,13K-22A'Typelnj.I S i,.~.~.1 ~ i~u~,~,l ~oo i ~0:~ i ~%~ i ~:o P.T.D. 2000260 Type testI P Test psi 3000 Casing 0 P/F P Notes: Pretest pressures obseved 15 min. & stable. "Monobore" injector. ( // Packer Depth Pretest Initial 15 Min. 30 Min. w~,,I ~Ty,~,n,.I s i~.v.~.I ~ i~u~,.,l ~oo i ~::ol ~o i ~o i,.,~,l , P.T.D. 2000260/Type testI P Test psi 1500 Casing 0 1550 1545 P/F Notes: Pretest pressures obseved 15 min. & stable. "Monobore" injector. 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 Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details April 1, 2003: I traveled to ConocoPhillips Alaska's Inc.'s (CPM) water injection well 3K-22A to witness an MIT. Nina Woods was the CPAI representative for the tests today. Well 3K-22A is a "monobore" injector and a wireline retrievable plug was set at 8315' MD to facilitate the tests. The pretest pressures were monitored and found to be stable and the MIT was then performed in two steps, with both the tubing and the casing passing their MIT. Summary: I witnessed successful MIT's on CPAI's water injection well 3K-22A in the Kuparuk River Field. M.I.T.'s performed' 2_ Number of Failures: 0 Attachments: Wellbore schematic (1) Total Time during tests: 2 hrs. CC: MIT report form 5/12/00 L.G. M IT KRU 3K-22A 4-1-03 JJ.xls 4/30/2003 Permit to Drill 2000260 MD 11290 --~ TVD DATA SUBMITTAL COMPLIANCE REPORT 4116~2003 Well Name/No. KUPARUK RIV UNIT 3K-22A Operator CONOCOPHILLIPS ALASKA INC 8658 ~" Completion Dat 3/19/2001 ,'""' Completion Statu 1WINJ Current Status 1WINJ APl No. 50-029-22759-01-00 UIC Y REQUIRED INFORMATION Mud Log N._~o Sample N_go Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name R~,,'''~' ~ Directional Survey (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No Interval OH I Dataset Start Stop CH Received Number Comments 11175 11290 Open 4/19/2001 Elevation Reference is ~' Ver LIS Verification Rpt Ver .L~' Verification Lo GR~amma Ray 25 Blu 11185 11185 11185 measured for Mean Sea Level 11290 , 1 119/2003 800 11290 Case 2119/2003 11290 Case 2/19/2003 Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Analysis Y / N R~.r.~.iv~.d ~ Daily History Received? Formation Tops Comments: Compliance Reviewed By: Date: l llooo Transmittal Form BAKER ... HUGHES INTEQ Anchorage GEOScienee Center ":':-':_, -"-:'~:~."."?:~_ . ........ ., '-'_, To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 3K-22A i! Contains the following: ', i! 1 LDWG Compact Disc :' (Includes Graphic Image files) ~i 1 LDWG lister summary 1 blueline - GRJDireetional Measured Depth Log * Note: No GR/Directional TVD Log was generated LAC Job#: 125102 Sent Receive~.~~~ ~ Date: Feb 12, 2003 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 RECEIVE[ FEB 1 9 2003 Alaska Oil & Gas Cons. Corem ,, :~.,,,.,~.~ ,.. ............. :..,~. i~,.' :.:.,. ............................ .... Won ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 11 Status of well Classification of Service Well Oil r'~ Gas [~ Suspended [~ Abandoned [~] Service r~ ~ Water Iniector 2. Name of Operator ' ~fl~l~ .7. Permit Number Phillips Alaska, Inc. ~, 200-026 3. Address~,.~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22759-01 4. Location of well at sudace ~' '. ':.' ............ , 9. Unit or Lease Name - o,, ..'.~ , :... ~ 3905' FNL, 4962' FEL, Sec. 35, T13N, R9E, UM (asp's 529304, 6008366) . .'~;. ':"fi' · Kuparuk Unit At Top Producing Interval ' ~'.~..~.~..~_. 10. Well Number 4705' FNL, 3631' FEL, SEC 26, T13N, R9E, UM (asp's 530613, 6012853) ' ," '~ "' , 3K-22Ai ..... ~'~ ~ 11. Field and Pool At Total Depth .' 1784' FNL, 2823' FEL, SEC 26, T13N, R9E, UM (asp's 531405, 6015777) Kuparuk Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 75 feetI ADL 25519 / ALK 2555 Kuparuk Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions March 10, 2001 March 16, 2001 March 19, 2001I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11290' MD / 6668' TVD 11185' MD / 6660' TVD YES [~] No r'] I 524, (nipple) feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD- GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 121' 30" 129 Sx AS I 7-5/8" 29.7# L-80 Surface 4887' 9-7/8" 393 Sx ASLW, 65 Sx AS I, & 410 Sx Class G 4-1/2" 12.6# L-80 4677' 11175' 6-3/4" 600 Sx Class G 11175' 11290' 3-3/4" Collapsed open hole 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) (Open Perle- Injection into Kupamk A Sands) 4-1/2" 4677' 4677' 9195' - 9450' MD; 6637'- 6651' TVD 9675' - 10171' MD; 6656' - 6669' TVD 10345' - 10470' MD; 6683' - 6688' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10685' - 10855' MD; 6687' - 6677' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10915' - 10930' MD; 6673' - 6672' TVD 10960' - 11060' MD; 6671' - 6666' TVD (See Sidetrack Summary for details) 27. PRODUCTION TEST Date First Injection Method of Operation (Flowing, gas lift, etc.) March 27, 2001 Water Injection Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Pedod > Flow Tubing Casing Pressure CalculaWd OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -1750 psi 24-Hour Rate > 386 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. ,-- ._o · This 10-407 is submitted as directed per the 10-401 form approved March 23, 2000 (Permit #200-026) · *A 10-403 was submitted to the AOGCC on 3/21/2001 for OPS S/D. It was given an approval # but was not sigr~d,. U.i Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplic~ ORIGINAL 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 of Kuparuk C Sand 8247' 6517' BTM of Kuparuk C Sand 8342' 6550' Top of Kuparuk A Sand 8584' 6603' BTM of Kuparuk A Sand 10580' 6687' RECEIVED JUL 1 g 2001 Alaska 011 & Gas Cons. Commission Arlchora.qe 31. LIST OF ATTACHMENTS Summary of 3K-22Ai CT Sidetrack Drilling Operations + End of Well Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed ' Title PAl Coil Tubin,q Drillin,q En,qineer Date ! , Dan Venhaus Prepared by Paul Flauf 564-5799. 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 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ORIGINAL BP EXPLORATION Page I of 1 Final Well I Event Summary 'Legal Well Name: 3K-22A Common Well Name: 3K-22A Event Name: REENTER+COMPLETE Start Date: 3/9/2001 End Date: 3/19/2001 DATE TMD 24 HOUR SUMMARY 31912001 11,110.0 (fi) Move rig to 3K pad. Spot over well. Pull off well. Drill rathole. 3/10/2001 11,110.0 (ft) N/U BOPE. Press test BOPE. Pull BPV. Press test lubricator. 3/11/2001 11,160.0 (ft) Drilled float collar, cement and float shoe 3/12/2001 11,110.0 (ft) Milled out float shoe and drilled to 11,187 ft BKB. Swapped to FIoPro. 3113/2001 11,191.0 (ft) Close sliding sleeve and PT. RIH w/noz & cleanout. RIH. Drill 6'. POH 3/14/2001 11,191.0 (ft) Ran 3 trips with Venturi Basket. Stuck at 10,280'. Disconnect. Run noz 3/15/2001 11,228.0 (fi) CIO well to 11,050 ft. RIH, recover fish. Pressure Deploy MWD BH^. 3/1612001 11,290.0 (ft) RIH. Tie-in, Drill horiz hole to 11290'. Stuck pipe/POOH. RIH w/jet n 3/17/2001 11,290.0 (ft) CIO liner with jet noz run. RIH w/MWD BHA, ream shales to 11,238' 3118/2001 11,175.0 (ft) Ream shales. Stuck pipe. Ream shales. POOH. Swap well to seawater. 3/19/2001 11,175.0 (ft) Frz prot. tubing, set BPV. N/D BOPE. RELEASED RIG AT 16:00 HR, 3119101 Printed: 716/2001 11:35:31 AM BP EXPLORATION Page 1 of 9 Operations Summary Report Legal Well Name: 3K-22A Common Well Name: 3K-22A Spud Date: Event Name: REENTER+COMPLETE Start: 3/9/2001 End: 3/19/2001 Contractor Name: NORDIC CALISTA Rig Release: 3/19/2001 Group: COIL .Rig Name: NORDIC 1 Rig Number: '.. Sub Phase. DescriPtiOn of Operations Date From - To 'Hours · Task Code 3/9/2001 03:00 - 00:00 21.00 MOB PRE Move rig to 3K pad. Rig over well at 12:00 hrs. Rat hole had been drilled 5 inches to far from well. Pull rig off well. Drill new rat hole. Repair broken hinge on cellar door before backing rig over well again. Rig on Standby rate from 12:00 - 00:00 hrs. Rig not over well by 00:00 hrs. 3/10/2001 00:00 - 02:00 2.00 MOB PRE Back rig over well. Position BOP stack over tree. 02:00 - 05:00 3.00 BOPSUI; DECOMP ACCEPT RIG AT 02:00 HRS, 03-10-01. N/U BOPE. Set mousehole. 05:00 - 06:30 1.50 RIGU DECOMP Set up berm for cuttings tank. Set green tank in position. Heat cellar. 06:30 - 08:00 1.50 RIGU DECOMP BOP test, Wait on Grease Crew to service tree. Leu Grimaldi with AOGCC waved witnessing BOP test. 08:00 - 08:30 0.50 RIGU DECOMP Serviced tree 08:30 - 19:45 11.25 RIGU DECOMP BOP test as per AOGCC regulations Testing Drilling choke manifold (extra). Tested H2S and Methane Alarms 19:45 - 20:00 0.25 RIGU DECOMP SAFETY MEETING, review BP valve pulling procedure. 20:00 - 22:45 2.75 RIGU DECOMP Retrieve BPV from wellhead. 4 separate runs to pull plug. 22:45 - 23:00 0.25. STMILL WEXlT SAFETY MEETING. Review procedure to run milling BHA. 23:00 - 00:00 1.00: STMILL WEXlT M/U 3.74" mill, 2.88" motor and MHA. Press test lubricator to 3500 psi. 3/1112001 00:00 - 02:45 2.75 STMILL WEXlT RIH with milling BHA. Hold 1000 psi WHP with drilling choke. Circ. Diesel returns to green tank, total of 50 bbls. 02:45 - 04:00 1.25 STMILL WEXlT Tag PBTD at 11096 f. Getting oil/gas up with bottoms up, circulate, holding 300 psi whp. 2.6 bpm, 1.6 bpm returns. 2900 psi. Divert oily returns to green tank. Well not cleaning up, still getting oily / gassy returns, dump oily returns. 04:00 - 05:30 1.50 STMILL IWEXlT Low on fluid, still getting some crude and gas to surface. Shut-in well, bullhead 0.2 bpm at 720 psi. Stop pump, SIWHP -- 620 psi. Bullhead at 0.2 bpm, 740 psi whp, while waiting for water. SlWHP of 620 psi with water column to 6660 ff tvd -- BHP of 3532 psi or kill wt of 10.2 ppg. 05:30 - 07:20 1.83 STMILL WEXlT Milling 4.5" liner float equipment. Start at 11095.6 ff MD. 2.4 bpm, 3000 psi, holding 400 psi whp. Recovering 20/40 proppant/carbolite over shaker. Well was Frac'd July 1999 with 19,000 lbs 20/40 carbolite. 11,098.5' at 0720 hrs 07:20 - 09:07 1.78 STMILL WEXlT Milling on wiper plug slowly 2.5 bpm @ 2910 psi CTP, WHP = 400 psi, I Cir at 1:1presently Some pee size rubber and carbolite on shaker. Building mud volume to 275 bbl. 11,100 f. 09:07 - 10:15 1.13 STMILL WEXlT Milling Qp = 2.4 bpm @ 2941 psi, circulating at 1:1 ration, Carbolite and pee size rubber on shaker. Bring Lube tech % up to 2% to assist in better sliding. 11,106 ft. 10:15 - 11:46 1.52 STMILL WEXlT Milling Qp = 2.4 bpm @ 3011 psi, circulating at 1:1 .WHP = 400 psi. ReP = 0.2 fpm Depth = 11124'. ReP slow due to mill construction 11:46 - 13:00 1.23 STMILL WEXlT Milling Qp -- 2.4 bpm @ 3287 psi, circulating at 1:1. ReP = 0.2 fpm Wt = 2400# Cement at shaker. Bleed (OA -4-1/2" * 7-5/8") down from 1140 psi to 680 psi 13:00 - 14:00 1.00 STMILL WEXlT PU and restarted mill at 11138', "Parameters as above". Milling at 0.1 to 0.3 fpm. Milling at 11150'. Some stacking due to mill configuration. 14:00 - 14:54 0.90 STMILL WEXlT Milled to 11159', WeB at 5000#, ReP at 0 fph, CT stacking 14:54 - 15:45 0.85 STMILL WEXlT PUH, wiper trip to 10400' (760') to sweep the hole. 15:45 - 17:36 1.85 STMILL WEXlT Milling on shoe Qp= 2.4, CTP = 3300 psi to 3700 psi (200 psi DP) WHP = 400 psi and circulating at 1:1. No fluid loss. Slow going with mill 17:36 - 20:20 2.73 STMILL WEXlT Milling on Shoe @ 2.4 bpm, CTP=3468 psi, 1:1 fluid ratio. WeB 5k to 8k down. Printed: 4/12/2001 9:34:31 AM ... BP EXPLORATION Page 2 of 9 Operations Summa Report Legal Well Name: 3K-22A Common Well Name: 3K-22A Spud Date: Event Name: REENTER+COMPLETE Start: 3/9/2001 End: 3/19/2001 Contractor Name: NORDIC CALISTA Rig Release: 3/19/2001 Group: COIL Rig Name: NORDIC 1 Rig Number: Date From - To Hours TaSk Sub Phase Description'of OperatiOns Code .... 3/11/20Ol 17:36 - 20:20 2.73 STMILL WEXlT Unable to stack much WOB. Mill with -3000~ string wt and only 50 psi motorwork. Back ream 100 f. No motorwork. 11,160 ft. 20:20 - 21:20 1.00 STMILL ~WEXlT Milling on shoe. 2.7 BPM. 3700 psi, 400 whp, full returns, only 50 psi motor work, stacking wt. Add 2 drums lube tex to get better wt transfer. No progress. Made 80 ft short trip, clean hole, no motor work. 11,160 ff. 21:20 - 23:10 1.83 STMILL WEXlT Milling, spud several times with mill. 2.7 bpm, 3930 psi, 400 whp, Very little motor work. No progress. Stack wt, only get 50 psi motor work. 11,160 ft. 23:10 - 00:00 0.83 STMILL WEXlT POOH to check motor and mill. 3/12/2001 00:00 - 01:30 1.50 STMILL WEXlT POOH to check motor and mill. 01:30 - 02:30 1.00 STMILL WEXlT Motor tested weak. C/O motor. Mill OK [10% worn]. Clear water courses. Clean out plugged choke line and hyd choke. Both lines were plugged .. with carbolite. Lines plugged while POOH at 250 ft. Circulating with 3.74" mill and BH^ carried more carbolite to surface on trip out. ~02:30 - 04:10 ~ .67 STMILL WEXlT RIH with milling BHA. 3.74" mill on 2.88" motor. 04:10 - 04:50 0.67 STMILL WEXlT Stack wt at 8100 ft while RIH. Jet through carbolite laying in horizontal section. RIH to TD. 04:50 - 06:45 1.92 STMILL WEXlT Milling, better motor work. [220 psi], 2.6 bpm, 3580 psi, Start milling at 11156.0 ft CTD. Full returns. Milled out float shoe at 11,158' CTD, [11175' BKB]. Drill formation to 11,170' CTD = 11,187' BKB. [12 ft form.]. 06:45 - 09:00 2.25 STMILL WEXIT Short trip thru horizontal section to cleanout carbolite. SWI at 10550' SIWHP = 566 psi.-- 10.1 ppg KMW. Open well on 400 psi and started pumps at 2.3 bpm., mix 2 ppb bio pill. PUll 09:00 - 09:52 0.87 STMILL WEXIT RIH, Qp = 2.3 bpm (~ 3115 psi CTP, WHP -- 400 psi Recovered sample from shaker(btm up) 65% Carbolite, 35% Shale, trace cement. Tagged and stalled 11151' PUH and restart 09:52 - 11:00 1.13 STMILL WEXlT Washing to bottom, Pump 10 bbl Hi-Vis Biozan sweep. Stopped at 11161' Stacking, PUH and motor stalled. Cir at 70% carbolite and 30% shale (mechanical weathered) 11:00 - 11:50 0.83 STMILL WEXIT PUH and make ready for mud swap, work CT while circulating WHP = 400 psi 11:50 - 13:15 .1.42 STMILL WEXIT Mud swap while working CT Circulated 188 bbl 9.5 ppg (Rig Micro Motions and mud scales) around and SWI. SIWHP = 148 psi after 15 min 13:15 - 13:30 0.25 STMILL WEXlT Open well to 50 psi and Check ciculation (1:1) WHP = 70 psi. CTP at 2.5 bpm = 3900 psi , 13:30 - 14:35 1.08 STMILL WEXIT RIH and motor work at 11150', Qp 2.3 bpm @ 3539 psi, WHP = 60 psi, W/R at 02 fpm to bottom at 11170' CTM 14:35 - 15:00 0.421 STMILL WEXIT PUH to 11,000' and shut down pump to check flow 1/4" stream coming out of the well. MW -- 9.6ppg 15:00 - 15:10 0.17 STMILL WEXIT RIH washing to bottom (off choke) Tagged at 11153' PU RIH to bottom to 11170 CTM. 15:10 - 15:20 0.17 STMILL WEXIT PUH to 11075' RIH to check 11153' interval, Clean at 11153' 15:20 - 16:30 1.17 STMILL WEXIT POOH, Tagged sliding sleeve at 4627" while POOH. Worked down and came up through 16:30 - 18:00 1.50 STMILL WEXIT Carbolite at shaker. Slowed down to keep from fill surface piping Plugged all surface lines in BOP stack. Worked on gaining circulation. Only circulation was through the displace lines for the'liner. POOH Printed: 411212001 9:34:31 AM Bp EXPLORATION Page 3'of 9 Operations Summary Report Legal Well Name: 3K-22A Common Well Name: 3K-22A Spud Date: Event Name: REENTER+COMPLETE Start: 3/9/2001 End: 3/19/2001 Contractor Name: NORDIC CALISTA Rig Release: 3/19/2001 Group: COIL Rig Name: NORDIC 1 Rig Number: Date From - TO Hours Task Sub Phase' Description of Operations Code 3112/2001 16:30 - 18:00 1.50 STMILL WEXlT slowly 18:00 - 19:00 1.00 STMILL WEXlT Closed SV (23 turns) Pop of well and install nozzle to flush the stack and unplug surface lines 19:00 - 19:15 0.25 STMILL OTHR ,WEXlT SAFETY MEETING, review steps to clear surface lines of carbolite. 19:15 - 21:00 1.75 STMILL OTHR ~WEXlT Circulate all surface lines clean. Prep rig floor for Halco slickline. 21:00 - 21:15 0.25 STMILL OTHR WEXlT SAFETY MEETING, Review slickline procedure to close sliding sleeve. 21:15 - 00:00 2.75 STMILL OTHR WEXlT Rig up Halco slickline. RIH with tools to shift sliding sleeve closed. 3/13/2001 00:00 - 01:30 1.50 STMILL OTHR WEXlT RIH with slickline tools and close sliding sleeve 01:30 - 02:00 0.50 STMILL OTHR WEXlT Pressure test inner annulus with diesel to prove sliding sleeve is closed. PT failed. Pumped 4 bbl to confirm failure (263' tubing length) 02:00 - 03:00 1.00 STMILL OTHR WEXlT POOH, re-dress tool. 03:00 - 04:45 1.75 STMILL OTHR WEXlT . RIH and shift sleeve closed. PT w/Little Red to 800 psi for 10 rain, OK, Released P to 400 psi and SI annulus POOH with WL WHP = 100 psi. 04:45 - 05:05 0.33 STMILL SAND WEXlT RU nozzle for cleanout run, PT Lubricator to 800 psi. Open MY and WHP = 290 psi Open set point at 150 psi on WH 05:05 - 07:45 .2.67 STMILL SAND WEXlT RIH at Qp = 2.4 psi, CTP = 3432 psi and WHP = 188 psi,.(on choke to start). OA temperature increased from 400 psi to 1250 psi, (thermal expansion). With approval from CPF3 PE, bleed down to approximately 675 psi '07:45 - 08:00 0.25 STMILL SAND WEXlT Open choke to 100 psi WHP while RIH at 10100' Displacing CT at 3.89 bpf Stopped at 11160' 08:00 - 11:45 3.75 STMILL SAND WEXlT POOH chasing material to surface Qp = 2.5 bpm, WHP = 80 psi. Hold 230 psi whp with choke at 3000 ft. 11:45- 12:00 0.25 STMILL SAND WEXlT Monitor Well. Welldead, noflow. 12:00 - 12:15 0.25 STMILL PROD1 SAFETY MEETING. Review pressure deployment BHA space out and operations. 12:15 - 13:30 1.25 STMILL PROD1 M/U MWD BHA #1 w/0.9 deg motor and 3.0" HYC Bi-center bit #1. 13:30 - 15:30 2.00 STMILL PROD1 RIH. Shallow test Baker MWD. RIH. 15:30 - 16:30 1.00 STMILL PROD1 Log tie-in with GR, added 5 ft to CTD. 16:30 - 17:00 0.50 STMILL PROD1 Tag TD at 11185 ft. Orient TF 17:00 - 17:15 0.25 STMILL PROD1 On bottom drilling. TF--201 deg. 1.6 bpm/3150 psi Free spin/3400 psi drilling 17:15 - 18:20 1.08 STMILL PROD1 Drill 11185'-11191'. Stalled, picked up, bit stuck. Pulled heavy/jerky with motor stalled to 11150', then pulled free. Maximum pull was 45k lbs, 22klbs over pull. Pull up to 11080', circulate 10 bbls of 2#/bbl biozan sweep. Circulate pill around. Call for venturi basket and jars. 18:20 - 20:15 1.92 STMILL PROD1 Bio sweep out BHA, POOH chasing sweep. 20:15 - 21:00 0.75 STMILL PROD1 Pump to ensure well is topped of with mud. Got 1 for 1 returns and took little fluid to fill well. Hold safety meeting prior to rigging down BHA. Monitor well for no flow test for 15 minutes. 21:00 - 00:00 3.00 STMILL JUNK PROD1 Rig down BHA ~2, standby for Venturi basket from Baker. 3/14/200t 00:00 - 00:30 0.50 STMILL JUNK PROD1 M/U venturi basket fishing BHA. 2 5/8" OD basket. 00:30- 02:30 2.00 STMILL JUNK PROD1 RIH to 11,130' 02:30 - 03:15 0.75 STMILL JUNK PROD1 Pump max rate, 2.1 bpm, 3980 psi, and RIH slow 11,130-11,161', 11,100-11,169', 11,100-11,182', 11,000-11,182 ft. and 10,900- 11,182 ft. Stack full wt at 11,182 ft CTD. 03:15-04:40 1.42 STMILL :JUNK PROD1 POOH. 04:40- 05:15 0.58 STMILL JUNK PROD1 Check basket for junk. Found 2 large 1 1/2" Chunks. (1 shale, 1 cement), and 1/2 of a coffee cup of other assorted chunks, mostly shale. 05:15 - 07:10 1.92 STMILL JUNK PROD1 RIH with BHA #5, Venturi basket run #2. 07:10 - 08:00 0.83 STMILL JUNK PROD1 Stop at 11125', kick on pumps to 2 bpm, 3500 psi CTP. RIH at 10 fpm. Printed: 4/12/2001 9:34:31 AM BP EXPLORATION Page 4 of 9 Operations Summar Report ~Legal Well Name: 3K-22A Common Well Name: 3K-22A Spud Date: Event Name: REENTER+COMPLETE Start: 3/9/2001 End: 3/19/2001 Contractor Name: NORDIC CALISTA Rig Release: 3/19/2001 Group: COIL Rig Name: NORDIC 1 Rig Number: Date From - To Hours TaSk Sub Phase Description of Operations Code 3114/2001 07:10 - 08:00 0.83 STMILL JUNK PROD1 Tag up at 11184'. Make 3 passes up and down over interval. On last down pass tagged up on something at 11165', got increase in pump pressure and loss of weight. Shoved obstruction to bottom and stacked weight on it. Pulled up to above Baker float valve, and SI pumps to POOH. 08:00- 10:15 2.25 STMILL JUNK PROD1 POOH, SI pumps when running accross open perfs. 10:15 - 11:15 1.00 STMILL JUNK PROD1 Dump Venturi basket run #2. Found more debris than last run. 5 or 6 large chunks about I 1/2" diam, and numerous chunks in the 1" range. Geologist clasified it all as hard shale. Does not appear to be hydrated or softened. No chunks of cement in this run. 11:15 - 13:25 2.17 STMILL JUNK PROD1 Run in hole with 3 1/8" venturi instead of the 2 5/8" one. Venturi run #3, BHA #6. Tag up at 10700', fell through on second tag. Continue RIH, Tag up at 10885', RIH, Tag repeatedly, keeps moving down slowly. 13:25 - 15:00 1.58 STMILL JUNK =PROD1 10890', kick on pumps at 2.2 bpm, 3880 psi CTP. Getting 2.1 bpm back. Wash down to 10940', set down. Pick up clean at 22klbs. Continue to wash down slowly. Only able to RIH at 5 to 10 fpm. Got weight back at 11044', able to RIH faster. Weight check 11130' clean pickup at 22klbs. RIH to 11177' CTM tag up. Wash up 11125' and back to TD 3 times. Clean pickups and easy RIH each time. Wash up to 10650', SI pumps. 15:00- 15:35 0.58 STMILL JUNK PROD1 POOH, Pumps down, hung up at 10460', dropped back down. Pulled up and tagged a 2nd time. Kick on pumps. Able to pull up through it with pumps on. 15:35- 16:20 0.75 STMILL JUNK PROD1 Pulled up to 10306', hung up. Dropped back down ok. Pulled up again with pumps on. Hung up. Tried RIH. Could not go down. Picked up pump rate to max. Packed off around tool getting very little returns. Tried stacking weight and pumping. No luck. Position at neutral wt, and circulate at 4000 CTP, getting 0.2 back for 1.8 in. 16:20 - 17:40 1.33 STMILL JUNK PROD1 Attempt to work pipe down and can't get free. Mix/pump 20 bbls of 150 klsrv pill. Pump at 1.8 bpm, 0.2 bpm back. Pump around at max rate, work pipe down. No luck. Pull max, no jar lick. Still stuck. Work pipe in up direction. No success. Continue to work pipe. 17:40 - 18:30 0.83 STMILL JUNK PROD1 Attempt to pump down backside. Able to inject at 0.7 bpm, 1400 psi whp. Try pressuring up with 60 k lbs on coil, and dropping whp. No success. 18:30 - 19:45 1.25 STMILL FILL PROD1 Pump down CT. and annulus press to 1400 psi at 3.0 bpm. Dump press with choke, twice with max down wt. and three times with max up wt. No luck. !No jar action. No returns. 19:45 - 21:30 1.75 STMILL FILL PROD1 ~Pump 5/8" steel ball to disconnect. Pump 15 bbls at 1.5 bpm. let ball drop for 30 min. Pump ball on seat at 26 bbls. Set down wt. pump up to 4500 psi. Hyd Disconnect did not shear, work pump 0 - 4500 psi. Hyd disconnect released at 4900 psi. 21:30 - 23:00 1.50 STMILL FILL PROD1 Still packed-off. Pull to 70K. Still stuck. Order out 60 bbls dead crude to spot down backside. Wait on crude. Hold 60K up wt. 23:00 - 00'.00 1.00 STMILL FILL PROD1 CT PULLED FREE, got returns again. Circ. 1.6 bpm ! 2100 psi, full returns. POOH. Normal 24K up wt. Cancelled crude truck. Top of fish at 10,270 ft. Fish = 9 ft long. Fish = 3.13" Venturi basket, 3" XO and 2.13" GS fishing profile. 3/15/2001 00:00 - 01:30 1.50 STMILL FILL PROD1 POOH with upper half of Venturi Basket BHA #3. Recover upper half of BHA. 01:30 - 03:15 1.75 STMILL FILL PROD1 RIH with 2.6" jetting nozzle BHA to clean out fill above fish. Hold 200 psi whp with choke in upper 6000 ft of well. Printed: 4112/2001 9:34:31 AM .. BP EXPLORATION Page 5 of 9 Operations Summary Report Legal Well Name: 3K-22A Common Well Name: 3K-22A Spud Date: Event Name: REENTER+COMPLETE Start: 3/9/2001 End: 3/19/2001 Contractor Name: NORDIC CALISTA Rig Release: 3/19/2001 Group: COIL Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Sub Phase Description of Operations Code . 3115/2001 03:15 - 03:45 0.50 STMILL FILL PROD1 RIH at 9000 ff at 60 fpm, 2.4 / 2.3 bpm, 3500 psi, Normal up / dwn wt. 03:45 - 04:00 0.25 STMILL ;FILL PROD1 RIH pushing Fish back to bottom, no wt loss when reached top of fish at 10,270 ft. Fish was laying free in liner. Push to 11,050 ft, while jetting liner clean. 2.512.5 bpm, 3380 psi, RIH at 35 fpm. Dwn wt = 7K. 04:00 - 06:25 2.42 STMILL FILL PROD1 POOH while jetting liner at 2.5/2.4 bpm, 3300 psi, full returns. POOH at 40 fpm in horizontal section. 24K up wt. Left fish top at 11,050 ft inside 4.5" liner. 06:25 - 07:30 1.08 STMILL' FILL PROD1 Tag up at surface, rig down nozzle. Make up BH^ #7, fishing string; GS spear, disc, jars, NRJ. 07:30 - 09:40 2.17 STMILL FILL PROD1 RIH with fishing BH^, Pump at .5 bpm while RIH from surface with WHP back pressure at 200 psi. 8000', increase rate to 1.1 bpm, drop back pressure to 0 psi. Run in clean to 9500', weight check 9500--23klbs up clean, weight check 10200' clean pickup at 23klbs. Weight check pumps at 0.5 bpm at 10905'=24klbs up with clean pickup. 09:40 - 09:55 0.25 STMILL FILL PROD1 Pump rate 0.5 bpm, RIH to latch fish. Did not see any thing at 11050', continued RIH Tagged up at 11165' (+12' for length of fish is same tag up as on Venturi run #3) Saw good set down and CTP increase indicating probably in fishing neck with GS spear. Drop pumps to 0, bleed CTP to zero. Pickup clean at 24klbs. Pickup and stack on it 3 more times to ensure fish is latched. No overpull at any time. 09:55 - 10:10 0.25 STMILL FILL PROD1 POOH at 50 fpm, pumps down, circulating accross the top to keep well full, holding 200 psi with Swaco super choke on WHP. 10:10 - 11:00 0.83 STMILL CIRC PROD1 Check valve leaking, SI kill line, repair valve. RIH slowly to keep coil from freezing. 11:00 - 14:00 3.00 STMILL FILL PROD1 Resume POH at 50 fpm, holding 200 psi on WHP. Had to gradually increase WHP to 750 psi to prevent swabbing as we POH. (3.125" Venturi basket inside of tubing.) 14:00 - 15:00 1.00 STMILL FILL PROD1 Tag up at surface. Recovered fish ok. Dumped venturi basket and recovered 2 coffee cups of large stones. Emailed picture to town. We will run drilling BHA. 15:00 - 16:20 1.33 STMILL PROD1 Pre deployment safety meeting. All rig hands. 16:20 - 18:00 1.67 STMILL PROD1 Begin making up BHA ~6 with pressure deployment. First deployment for this crew. Problems with slickline unit. (Hose backed off) and with lubricator (No-Go swivel assembly pulled to packoff and would not fall) 18:00 - 19:00 1.00 STMILL PROD1 Change out rig crews, hold pre deployment safety meeting with night tour. 19:00 - 23:00 4.00 STMILL PROD1 Break down lubricator and pull slickline free. M/U Lubricator. Set motor and bit in stack. M/U deployment bar, orientor and Petredat press sub in mouse hole and pull into lub with slickline. M/U MWD in mousehole. M/U MWD to press sub and pull all into lubricator. M/U motor and MWD. Orient MWD highside. Strip lub down and press test. Flag slickline with master flag. Open master. RIH with BHA on slickline and land on NO-Go. Flag slickline. Pick up 4 ft to reach TIW valve and flag slickline. Close pipe rams on deploy bar. Pull test against slips. Stand back iub. M/U MHA on CT. M/U 5 ft lub to injector head. Set inj head above table and M/U MHA to torque sub. Open TIW valve. Strip down injector. Press test lub. Open slips. Pressure deployment complete. 23:00 - 00:00 1.00 STMILL PROD1 RIH with MWD drilling BHA with 0.9 deg motor and 3.0 bi-center bit. 3/16/2001 00:00 - 01:15 1.25 STMILL PROD1 RIH with MWD BHA with 0.9 deg motor and Hycalog 3" bi-center bit. Printed: 4/12/2001 9:34:31 AM BP EXPLORATION Page 6 of 9 Operations Summa Report Legal Well Name: 3K-22A Common Well Name: 3K-22A Spud Date: Event Name: REENTER+COMPLETE Start: 3/9/2001 End: 3/19/2001 Contractor Name: NORDIC C^LISTA Rig Release: 3/19/2001 Group: COIL Rig Name: NORDIC 1 Rig Number: Date From 'To Hours Task' Sub Phase Description of .OperatiOns . . · Code 3/16/2001 01:15 - 02:15 1.00 STMILL PROD1 Log tie-in with GR. Add 3 ft to CTD. 02:15-02:30 0.25 STMILL PROD1 RIHtoTD. Tag at11,188 ft. Upwt=22K. 02:30 - 03:15 0.75 STMILL PROD1 Orient TF. 03:15 - 04:15 1.00 STMILL PROD1 Drilling, TF = 170R, 1.6 ! 1.6 bpm, 3100 psi, ROP = 20 fph, Stacking full wt to drill ahead [-8000 lbs at surface]. Up wt -- 23 k. Dwn wt = 6K off bottom. 11210 ft. Added 2 drums lubtex to reduce drag. Total lubtex = 3.5% 04:15 - 06:00 1.75 STMILL PROD1 Drilling· TF - 170L, 1.8 / 1.8 bpm. 3450 psi, ROP = 15 fph, Stacking full wt. -8000 lbs at surf. Incl. -- 89 deg. MD = 11,228 ft. 06:00 - 07:00 1.00 STMILL PROD1 Drilling, TF = 170L, 07:00 - 07:15 0·25 STMILL PROD1 ' 11239' at 07:00, Drilling hard shale. Poor weight transfer. Weight---9000 lbs, 1.7 bpm/3500 psi, 180 deg TF, 0 psi WHP. 07:15 - 07:20 0.08 STMILL PROD1 Short trip up to shoe, rattty pickup pulling 24-26klbs. 07:20 - 07:40 0.33 STMILL PROD1 Resume drilling, stall, tried to pickup, bitstuck, pulled 45klbs, ran back ~n, got free. Pull up into csg ok. normal up weight at shoe is 24klbs. 07:40 - 09:00 1.33 STMILL PROD1 Resume drilling, 09:00 - 09:20 0.33 STMILL PROD1 11260' at 09:00, drilling shale, 1.7 bpm/3500 psi1170 deg TF, Made another short trip to shoe, and weight seems to have improved a bit. We are up to 2000 lbs at surface and drilling. Will add an additional 4 drums of lubtex to increase it to 5.5%. 09:20 - 09:30 0.17 STMILL PROD1 Need to orient around to 30R, hold 200 psi backpressure, orient. 09:30 - 10:00 0.50 STMILL PROD1 Resume drilling directional, TF=15L 1'0:00 - 10:30 0.50 STMILL PROD1 11273' at 10:00, drilling shale, 1.7 bpm/3300 psi/0 deg TF. 10:30 - 11:00 0.50 STMILL PROD1 11286' at 11:00, drilling shale, 1.7 bpm/3700 psi173 deg R TF. 11:00 - 11:55 0.92 STMILL PROD1 11290', wiper trip to 8000'. Cleaner pickup off bottom, ratty at 11165', 15klbs overpull. 11:55 - 12:50 0.92 STMILL PROD1 Stuck at 10658', Packed off, worked pipe, pulled max, got free. Continue wiper trip. 12:50 - 13:10 0.33 STMILL PROD1 Stuck at 9415', Lost returns, (differentially stuck?) worked pipe, pulled free,, got returns back. Continue wiper trip. 13:10 - 1.3:20 0.17 STMILL PROD1 9245', lost returns,.but able to pull up hole. Tried SI pumps and RIH, . unable to go down.. PUH ok. Continue wiper trip with 0 returns, . pumping at 1.5 bpm, 3650 psi. 13:20 - 13:30 0.17 STMILL PROD1 .9213', stuck, pulled max, moving slowly, no returns. 9185', above ~perfs, no returns, pulling slow at 65klbs, 9177', pulled free. 9160', i stuck, motor work each time we pull free. 9130', stuck, pulled max, poped free. 9110', stuck, pull to 65klbs, stuck solid for 10 minutes, pulled free, can't go down. Continue to pull up. 9090', stuck, no 13'30 returns. Pulled free, got returns hold here at 9080', mixing hi vis pill. · - 14:00 0.50 STMILL PROD1 At 9078', circulate while building hi vis sweep. Full returns, pumping 1.9 bpm. 14:00 - 14:25 0.42 STMILL PROD1 10 bbls of 150k Isrv sweep away, chasing with mud. Sample of returns shows fine shale cuffings and some chunks of gel polimer? 14:25 - 16:00 1.58 STMILL PROD1 Hi vis sweep around motor, pulling OOH at 38 fpm. 7800', hung up again. Getting motor work, pulled free. 16:00 - 16:50 0.83 STMILL PROD1 5000', apply 200 psi WHP with choke, continue pulling. Easier now, POOH at 70 fpm. 3600', lost 200 psi CTP. Went from 4000 to 3800 psi. 16:50 - 17:30 0.67 STMILL PROD1 1300', send another 10 bbl hi vis sweep, timed to exit BHA as we near surface. 17:30 - 18:00 0.50 STMILL PROD1 Tag up at surface,wait for crew change. Printed: 4112/2001 9:34:31 AM BP EXPLORATION Page 7 of 9 Operations Summa Report Legal Well Name: 3K-22A Common Well Name: 3K-22^ Spud Date: Event Name: REENTER+COMPLETE Start: 3/9/2001 End: 3/19/2001 Contractor Name: NORDIC CALIST^ Rig Release: 3/19/2001 Group: COIL Rig Name: NORDIC 1 Rig Number: Date From'- To ' Hours Task Sub . code. Phase Description of OperatiOns 3/1612001 18:00 - 18:30 0.50 STMILL PP,OD1 Safety meeting prior to undeploy of BHA #8. 18:30 - 18:45 0.25 STMILL PROD1 SI pumps, do no flow test. 18:45 - 20:00 1.25 STMILL PP,OD1 L/O MWD BHA, found 1 MWD monel was bent and had several 3ressure rings in the body. Send for replacement. Bit OK. MIU jet nozzle BHA to cleanout liner with higher pump rates. 20:00 - 21:45 1.75 STMILL FILL PROD1 RIH to jet out shale / fill in horizontal liner. Hold 200 psi whp. 21:45-22:10 0.42 STMILL FILL PROD1 RIH to 9600 ft. nowtloss, pump 2.1bpm l 3050 psi. Plugged line at surface. Clean out choke line and micromotion meter. 22:10 - 22:45 0.58 . STMILL FILL PP,OD1 P,IH at 50 FPM, 2.6 / 2.8 BPM, 3900 psi, P,IH to liner shoe at 11,176 ft. with no wt loss and full returns. 22:45 - 23:15 0.50 STMILL FILL I PROD1 Sat down full wt at liner shoe. Unable to get past with nozzle. Overpull when pick up. Work free OK. Fill / debris at start of open hole. 23:15-00:00 0.75 STMILL FILL PROD1 Stage 50 bbls seawater at 2.6 / 2.6 bpm, 3900psi, fullreturns. RIHto 11,080 ft jetting seawater. Chase SW with FIoPro at max rate. 2.6 / 2.6 bpm and 3900 psi. Full returns. RIH to 11,170 ft with FIoPro out nozzle. POOH at 30 fpm while chasing SW to surface. 311712001 00:00 - 02:30 2.50 STMILL FILL PROD1 RIH with nozzle.to shoe at 11176 ft. Circ at max rate and chase 50 bbl ' sewater pill to surface. POOH at 30 FPM, 2.8 ~2.8 bpm, 3900 psi, Dump SW pill when it reached surface. Some shale, carbolite and 30% scale in cuttings on shaker. About 5 gals recovered. POOH circ. at max rate. Hold 200 psi whp. .02:30 - 03:00 0.50 STMILL FILL PROD1 . Shut in well with 200 psi. Clear debris from choke. Lay out jet nozzle ;BHA 03:00 - 03:40 0.67 STMILL PROD1 = M/U MWD BHA with 0.9 deg motor and 3.0" bi-center bit. 03:40 - 05:45 2.08 STMILL PROD1 : RIH with MWD BHA. Hold 200 psi whp. P,eam across horizontal :section while RIH. 05:45 - 06:20 0.58 STMILL PROD1 Log tie-in, added 1 ft to CTD. 06:20 - 07:00 0.67 STMILL PROD1 RIH, tag up at 11184'. Current TF--90L, orient around to 150 P,. Attempt to P, IH. Still can't make it in. 07:00 - 08:50 1.83 STMILL PROD1 Drill 11180'-11188', picked up pulled to 45klbs, 20k overpull, pulled free. Tried to P,IH, but hit junk at 11167', getting motor work. Get through it, RIH free spin 1.7/3400/TF164R. Drill to 11199', pick up overpull to 34klbs, RIH, getting motor work at 11195'. This shale must be collapsing, or coming in on us. Drill back down to 11199' stall, pull to 34k to get free, normal pickup 25k. 08:50 - 09:00 0.17 STMILL PP,OD1 P,IH tag up drill, tag up stall at 11185'. Well seems to be giving up shale. Pick up, P,IH, motor work at 11167'. 09:00 - 09:40 0.67 STMILL PROD1 Reaming at 11167', surface choke plugged off. 500 psi on WHP, go to bypass and cycle choke to clean up. Getting pea sized gravel accross the shakers. Drill to 11175', pickup at 29klbs. '09:40 - 10:50 1.17 STMILL PP,OD1 . Continue to' get work just outside the shoe. RIH, tag, stall, PU heavy, RIH tag stall, repeat. 11166', 11166', Short trip up to 11090, resume reaming. 11190', pull to 40k, 11199', 11204', 11208', 11195', 11169', 10:50- 12:30 1.67 STMILL PP,OD1 Working/reaming 11175', 11214', 11218', 11203', Now holding 150 psi on WHP when drilling, 450 psi with pumps off. 10205', 11192', 11100', etc. 12:30 - 13:00 0.50 STMILL PROD1 11205', upper section of open hole seems to be behaving a bit better. Still reaming, but haven't lost any hole since we started holding back pressure. 13:00 - 13:40 0.67 STMILL PP,OD1 11225',This section of hole appears to be much more well behaved. The rubble zone extends from the shoe at 11174' to about 11205'. Continue drilling. 1.4 bpm/3000 psi1165 degR TF, 150 psi WHP. 13:40 - 14:00 0.33 STMILL PROD1 11230', P,IH more easily, pickup clean at 11238'. Fighting high solids in Printed: 411212001 9:34:31 AM BP EXPLORATION Page 8 of 9 Operations Summa Report Legal Well Name: 3K-22A Common Well Name: 3K-22A Spud Date: Event Name: REENTER+COMPLETE Start: 3/9/2001 End: 3/19/2001 Contractor Name: NORDIC CALISTA Rig Release: 3/19/2001 Group: COIL Rig Name: NORDIC 1 Rig Number: · Sub Phase DesCription of Operations Date FrOm 'To' Hours.' Task Code - 3/17/2001 13:4o - 14:00 0.33 STMILL PROD1 mud. Call for new mud. 14:00 - 16:00 2.00 STMILL STAB PROD1 11238', Waiting for new mud, short trip. 16:00 - 17:00 1.00 STMILL STAB PROD1 Pulled clean to 8200', no problems, no pulls. Started pulling heavy at 8215', lost returns. Pumping 1.7 bpm, pulled 35klbs, got free, pulling heavy, pull to 8054' heavy, could not go down. Stuck, pulled max. No returns, can't go 'down, can't get returns. Try holding max weight, cycling pumps. 17:00 - 17:50 0.83 STMILL STAB PROD1 Made it from 8054' to 7988', pulling very slowly while holding 65klbs. No returns when circulating. 17:50 - 18:25 0.58 STMILL STAB PROD1 , Pulled slow to 7830', pulling 65 klbs (Max) and pulling at 7 fpm. Finally , popped free. Continue up for wiper trip. Debris appeared to be differenet that yesterday. We didn't see large chunks falling by the motor this time, with subsiquent motor work. We saw no motor work at all during stuck operations. Looked more like smaller debris or clays packing off. 18:25- 19:40 1.25 STMILL STAB PROD1. Wiped up to 6500' (35 deg hole angle). Run back in hole. Stack wt at 8900'ft. ream down 100 ft to clean up liner. RIH to 11,170 ft. Stack wt at shoe. 19:40 - 20:30 0.83 STMILL STAB PROD1 Wait on new FIoPro. Circ at min. rate near shoe. 20:30 - 21:30 1.00 STMILL STAB PROD1 Ream Shales below shoe to 11,189 ft. Some 20 K overpulls. Cleaned up. 21:30 - 23:30 2.00 STMILL STAB PROD1 Ream shales below shoe to 11,193 ft.. Unable to get deeper. Stacking max. wt at surface [-8K]. 30K overpull off bottom. 23:30 - 00:00 0.50 STMILL STAB PROD1 Short trip thru horizontal liner to reduce drag.' Up wt = 28-30K, 1.8 bpm, 3600 psi. POOH at 40 fpm. 3/18/2001 00:00 - 01:20 1.33 STMILL FILL PROD1 Wiper trip to 7500 ft. 5K overpulls at 7900 and 7800'. 1.9 / 1.7 bpm, 3600 psi, 01:20 - 02:00 0.67 STMILL. FILL PROD1 Overpull at 7630', lost returns, pulled 30K over. RIH, Work free. RIH 200 ft, no returns, pull up to 7580 ft. pull up to 65 K. Work free. No returns. 02:00 - 02:30 0.50 STMILL FILL PROD1 Pull up to 65K and POOH at 2-5 fpm from 7577 - 7460 ff. No returns. Pulled free at 7460 ft. Full returns again. Pull up to 7000 ft with full returns. NOTE: We are unable to lift built up debris in the annulus above the BHA to surface, due to open perfs below taking fluid and allowing debris on backside to fall and stick pipe. 02:30 - 03:30 1.00 STMILL FILL PROD1 RIH to CIO fill. Saw motor work at 7460 ft. RIH to 7500', pull up to check overpull. 26K up wt, full returns, 1.8 bpm, 3700 psi.. RIH to 7550 ft. Circ. bottoms .up with full returns. Small amount of ground up shale seen. 03:30 - 05:00 1.50 STMILL FILL PROD1 RIH to 7650 ft. Pick up OK. RIH to 7750 ft. Pick up OK. Circ. bottoms up. Poor recovery of shale at shaker. 05:00 - 06:30 1.50 STMILL FILL PROD1 RIH to 8700 ft. Circ. very high viscosity FIoPro 30 bbl pill. Maximum that could be pumped, trying to get fill in liner out of well. Pump max rate of 2.0 bpm, 4050 psi. full returns. 06:30 - 07:30 1.00 STMILL FILL PROD1 Pull from 7700' to 6500', No motor work, no pulls, stop at 6500', circ out hi vis sweep, looking for debris. Getting mostly fines. No large chunks. 07:30 - 08:15 0.75 STMILL FILL PROD1 Recovered all of pill, no significant debris recovered. RIH 08:15 - 08:45 0.50 STMILL FILL PROD1 RIH to 8300', no motor work observed, no weight loss or loss of circulation seen. PUH to check for overpulls or work. Printed: 4112/2001 9:34:31 AM BP EXPLORATION Page 9 of 9 Operations Summa Report Legal Well Name: 3K-22A Common Well Name: 3K-22A Spud Date: Event Name: REENTER+COMPLETE Start: 3/9/2001 End: 3/19/2001 Contractor Name: NORDIC CALISTA Rig Release: 3/19/2001 Group: COIL Rig Name: NORDIC 1 Rig Number: Date From -.To Hours Task Sub Phase DeScriptiOn of Operat'i°ns ... Code 3/18/2001 08:45 - 09:45 1.00 STMILL FILL PROD1 No motor work or overpulls observed. RIH to attempt to clean hole.8knj 09:45 - 09:55 0.17 STMILL FILL PROD1 Tag fill at 11150', pick up 26klbs up, kick on motor, start reaming down at 11148' only making 100 fph! Drill to 11155', had to pull 41 klbs to pick up off bottom. Pull up for tie in pass to find out where we are. 09:55 - 11:35 1.67 STMILL" PROD1 Log tie in pass down from 10900'. Make +28' correction, check tie in again at 10925', 11:35 - 11:40 0.08 STMILL PROD1 Orienting to 180 tool face. ,11:40 - 12:00 0.33 STMILL PROD1 Back at shoe, tag up at 11175, shale has collapsed/swelled again. Resume milling at shoe. Make it easily to 11180', heavy pickup at 35klbs. Resume milling, not making much progress. 12:00 - 12:50 0.83 STMILL PROD1 Pumping 5 bbl hi vis sweep every 15 minutes, continue milling at 11184'. Mill to 11185', pick up at 40klbs. Resume milling back to 11185', pickup at 45klbs. 12:50 - 13:20 0.50 STMILL PROD1 Getting pea sized gravel ac, cross the shakers. 13:20 -.16:20 3.00 STMILL PROD1 Not making any progress on reaming shale.. Keeps falling in on us. Pickups.keep getting worse. Only a matter of time before we get stuck. Contact/discuss with town. Decide to call it a day on this one. POOH pump 10 bbls hi vis sweep off bottom, pump 20 bbls hi vis sweep at 9300' to clean 60 deg area prior to pulling through. 16:20 - 18:30 2.17 STMILL PROD1 POH at 25 fpm, picked up speed to 50 fpm when we got to 6000'. Hung up at 5101', pulling heavy. Pulling 65klbs at 5015,'1ost returns, broke free at 4980', getting returns again. Slow speed to 25 fpm. Every time we speed up we pull into debris. 18:30 - 19:30 1.00 STMILL PROD1 Tag up at surface with BHA 10,' recover 100% of BHA. 1 chipped cutter on bit. change to nozzle and stinger. 19:30 - 22:15 2.75 STMILL PROD1 RIH to PBTD to recover FIoPro and turn well over to seawater. 22:15 - 00:00 1.75 STMILL PROD1 Stop nozzle at 11,150 ft. Pump seawater and recover 10 ppg FIoPro in rig pits. Haul FIoPro to MI for storage. Pump 2.2 bpm at 3600 psi. POOH. Stop at 2000 ft to freeze protect tubing with diesel. 3/19/2001 00:00 - 00:45 0.75 STMILL PROD1 Freeze protect 4 1/2" tubing with diesel from 2000 ft to surface. Pull to surface. Close Master Valve. SlWHP = 700 psi. 00:45 - 03:15 2.50 STMILL PROD1 Pump Nitrogen and displace fluid from CT. Bleed off N2 pressure from coil. i Clean rig mud pits. 03:15 - 03:30 0.25 STMILL PROD1 ~SAFETY MEETING, Review procedure for setting BPV in wellhead. 03:30 - 06:00 2.50 STMILL PROD1 Set BP valve in wellhead. First attempt failed. Fix seals in BPV. Set again. · Held pressure OK. Closed master and swab valves. 06:00 - 11:30 5.50 STMILL PROD1 Lay down 1" CSH in derrick. 11:30 - 14:00 2.50 STMILL PROD1 Nipple down stack. 14:00 - 15:00 1.00 STMILL PROD1 Nipple up tree cap and pressure test. 15:00 - 16:00 1.00 STMILL PROD1 Remove slickline unit from rig floor. RELEASED RIG AT 16:00 HRS, 03/19/01. Change out CT reel with Peak crane. Prepare to move rig to Milne Point. Well freeze protected and shut in. Printed: 4/1212001 9:34:31 AM Fwd: FW: FW: 3K-22A operations shutdown] ( Subject: [Fwd: FW: FW: 3K-22A operations shutdown] Date: Thu, 10 May 2001 14:01:11 -0800 From: Jack Hartz <jack_hamz~admin.state.ak.us> Organization: AOGCC To: "Lisa M. Weepie" <lisa_weepie~admin.state.ak.us> Lisa, Please file a copy of this email in the 2 well files noted - 3K-22 (Permit % 197-066, API 0292275900) and 3K-22A (Permit % 200-026, apl 0292275901). Thanks, Jack Subject: Re: FW: FW: 3K-22A operations shutdown Date: Thu, 10 May 2001 13:59:47-0800 From: Jack Hartz <jack hartz~admin, state.ak.us> Organization: AOGCC To: "Rauf, Paul C" <RaufPC~BP.com>, "Venhaus, Dan E" <VenhauDE~bp.com> CC: Wendy Mahan <wendy mahan~admin.state.ak.us>, Thomas E Maunder <tom maunder~admin, state.ak.us>, Robert Crandall <bob_crandall~admin. state.ak.us>, Camille Taylor <cammy taylor~admin, state.ak.us?, Stephen Memains <stev~-_mcmains~admin.state.ak.us> Subject: Well completion Report and Sundry Applications - 3K-22 (Permit % 197-066, API 0292275900) 3K-22A (Permit % 200-026, apl 0292275901) Dan, After our conversation, I believe the best way to proceed with the disposition of 3K-22 and 3K-22A is as follows. - File a 10-407 to complete the paperwork on 3K-22A as an injection service well. Even though the drill out was not 100% of what you anticipated, the project was completed. You mentioned that the well designation and API number may have already been changed in your data bases and in the Production Accounting software which would complicate changing back to the 3K-22. - There is no need to file a 10-403 for an operation shutdown on 3K-22A. We can send that paper work back to you or file it without any action here. - The AOGCC is able to administratively "abandon" the permit for 3K-22 without further paperwork from the operator. We inform the operator that the administrative procedure has been done which provides the operator a paper trail of our action. If this procedure meets your needs and is agreeable to you, inform Paul Rauf that he can file the 10407 on 3K-22A as a completed injection service well. AOGCC will take care of the paper on 3K-22 and copy the operator of our action. Call me if you have any questions. Jack Hartz "Rauf, Paul C" wrote: > Hi Jack, 1 of 4 5/10/01.4:29 PM Fwd: FW: FW' 3K-22A operations shutdown] > Got your voicemail message & I am responding to it. My email address is > raufpc~bp.com. > Thanks > Paul Rauf > > ..... Original Message ..... > From: Dan Venhaus [mailto:dvenhaus~ppco.com] > Sent: Monday, April 30, 2001 1:56 PM > To: wendy_mahan~admin.state.ak, us > Cc: raufpc~bp, corn > Subject: Re: FW: 3K-22A operations shutdown > > Wendy, > > Per our telephone conversation earlier today, we have no future plans to > re-enter this well and perform thru-tubing drilling. The 115' of openhole > that was drilled collapsed and we have no intention at this time of > attempting to reclaim it via redrilling or sidetracking the current well. > The only plan for 3K-22Ai is to resume injection. I hope this answers any > questions. > > With approval of the sundry and per your request, we'll follow up with a > 407 completion report. > > Paul, see any problems here? > > Thanks, > > Dan Venhaus > Forwarded by Dan Venhaus/PPCO on 04/30/2001 01:44 PM ...... Tom Maunder <tom maunder~admin.state.ak, us> 03/26/2001 08:41 AM To: Dan Venhaus/PPCO~Phillips cc: Subject: Re: FW: 3K-22A operations shutdown Dan, I have talked with Bob Crandall requiring anything further at 3K-22. After examining the information you provided in your email, we are of the opinion that the injection water will still be confined to the A sand. You have approval to resume injection. Please call if you have any questions. Tom Maunder, PE Petroleum Engineer AOGCC Dan Venhaus wrote: > Tom, 2 of 4 5/10/01 4:29 PM Fwd: FW: FW: 3K-22A operations shutdown] > > This is a follow-up to my phone message. > > I discussed the questions you raised with the geologist and pad engineer. > The shale we encountered right outside the shoe is the A5/A6 interval, the > existing horizontal is perforated in the A3/A2 sands, and the targeted > extension was turn the well back into the A3/A2 sands. Therefore all of > the well, even the new hole, is still in the A-sand interval. > > Some TVDs to help explain: > > Top perf - 9195' md (6561' ss) > Bottom perf - 11060' md (6591' ss) > Top of drilled hole (ie, float shoe) - 11175' md (6586' ss) > Bottom of lost drilled hole - 11290' md (6594' ss projected) > > The new hole is only 5' TVD higher than the last perforated section and > never broke out of the A-sands. As such this well was to be completed wi th > a slotted liner and the A5/A6 would have seen the injection water > regardless. > > I hope this answers your questions. > > Thanks, > > Dan Venhaus > > > > > > > > > > > > > > > > > > > > > > > > Forwarded by Dan Venhaus/PPCO on 03/19/2001 05:25 PM "Venhaus , Dan E" <VenhauDE~bp. com> 03/19/2001 04:16 PM To: Dan Venhaus/PPCO~Phillips cc: "Rauf, Paul C" <RaufPC~bp. com> Subject: FW: 3K-22A operations shutdown > ..... Original Message ..... > From: Tom Maunder [mailto:tom maunder~admin.state.ak.us] > Sent: Monday, March 19, 2001 8:43 AM > TO: Venhaus, Dan E > Subject: Re: 3K-22A operations shutdown > > Dan, > Further to our discussion...how much new hole was planned for the > extension? > You will need to formally file the 403 paper work for the SD. I look > forward > to the information after you talk to the geologist regarding how the newly > drilled and lost section corresponds TVD wise with the existing perfora ted > intervals. Thanks. > Tom Maunder > > "Venhaus, Dan E" wrote: > > > Tom r >>> > > More bad news] Nordic 1 has been unsuccessful on the 3K-22A extension 3 of 4 5/10/01 4:29 PM Fwd: FW: FW: 3K-22A operations shutdown] > > > (PTD#200-026). We encountered a shale just outside of the float > > equipment > > > and drilled approximately 100' of it. The new hole collapsed after a > > wiper > > > trip and we have failed to get back the 100'. Every short trip > required > > > re-drilling the shale. The last tag was 10' outside the shoe ~ 11185' > - >>no > > > chance of getting a liner in the extended hole. >>> > > > The well has been swapped to seawater with diesel freeze protect and > > Nordic > > > 1 is preparing to rig down. We are requesting a shutdown of > opera t ion s. >>> > > > Dan Venhaus > > > > (See attached file: tom maunder, vcf) > (See attached file: tom_maunder, vcf) Sr. Petroleum ReserVoir Engineer Alaska Oil & Gas Conservation Commission~ Jack Hartz <jack hartz~admin, state.ak.us> Sr. Petroleum Reservoir Engineer Alaska Oil & Gas Conservation Commission 4 of 4 5/10/01 4:29 PM i. Baker Hughes INTEQ( Baker Hughes INTEQ Survey Report HUGHES INTEQ Company: Phillips Alaska, Ino. Field: Kuperuk River Unit S#e: KRU 3K Pad Well: 3K-22 Weglm~: 3K-22A Date: 4/11/2001 Time: 16:09:47 l~e: Co-ordinate(NE) Referem=e: Well: 3K-22, True North Yerfled (TYD) ~e~: 3K-~ R~ 75.3 ~n ~ Refers: W~l (0.~N,0.~E,21 .~i) ~ey C~on M~: Minimum Cu~m Db: S~ Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Ceo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Cooniinate System: Well Centre C, eoma~netic Model: BGGM2000 Site: KRU 3K Pad UNITED STATES: North SLope Site Position: Northing: 6008365.50 ff Latitude: 70 26 2.159 N From: Map Easting: 529304.20 It Longitude: 149 45 39.995W Position Uncertainty: 0.00 ff North Reference: True Ground Level: 0.00 tt Grid Convergence: 0.23 deg Well: 3K-22 Slot Name: WellPesition: +N/-S 0.00 It Northing: 6008365.50 It Latitude: 70 26 2.159 N +E/-W 0.00 It Easti~g: 529304.20 It Longitude: 149 45 39.995 W Position Uncertainty: 0.00 It Wellpath: 3K-22A Drilled From: 3K-22 500292275901 Tie-on Depth: 11175.00 It Current Datum: 3K-22 Rig HeiSt 75.30 It Above System Datum: Mean Sea Level Magnetic Data: 12/20/2000 Declination: 26.28 deg Fiekl Strength: 57428 nT Mag Dip Angle: 80.74 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction It tt It deg 0.03 0.00 0.00 21.00 Survey: MWD Start Date: 3/18/2001 Measured While Drilling Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation MD TVD ff 11175.00 6660.82 Kick-off Point 11290.00 6668.47 Projected TD .. Survey MD Incl Azim TVD SSTVD NIS E/W ASP- Y ASP- X DLS VS ff deg deg ff ff ff It ff ff deg/100it It 11175.00 93.02 14.73 6660.82 6585.52 7289.22 2101.31 6015662.19 531376.65 0.00 7558.11 11211.17 58.59 13.97 6660.32 6585.02 7324.25 2110.27 6015697.25 531385.48 12.43 7594.03 11243.80 82.88 13.27 6662.74 6587.44 7355.86 2117.93 6015728.89 531393.01 17.63 7626.28 11290.00 82.88 13.27 6668.47 6593.17 7400.48 2128.45 6015773.55 531 403.36 0.00 7671.71 APR 1 Alaska Oil & Gas Cons. Commissi¢,n ,Anchorage Co-ord~nate IN/E 4e~erencE Wr~lI CrCntm 3K-22 True North Vertma tqV[ Reference System Mean Sea Leve Slot- 000N 000E Seebon tVS1Relemnc~ 3K.22 (£~g 7400 / 2000 20562100 2150 2200 2250 23b0 2350 24~30 7556 7583 7610 7637 7663 7690 7717 7744 7771 7797 7824 7851 7878 7905 7931 7958 7985 8012 8039 Vertical Section at 2t,00°[ft] . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _X Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 3905' FNL, 4962' FEL, Sec. 35, T13N, R9E, UM At top of productive interval At effective depth 1890' FNL, 2849' FEL, Sec. 26, T13N, R9E, UM At total depth 1788' FNL, 2824' FEL, Sec. 26, T13N, R9E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 121' SUR. CASING 4853' LINER 6498' 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X (asp's 529304, 6008366) (asp's 531379, 6015672) (asp's 531405, 6015773) 6. Datum elevation (DF or KB feet) RKB 75 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3K-22Ai 9. Permit nu/~er / approval number 200~)'26 10. AP~umber /,'50-029-22759-01 /,1X~ Field / Pool / Kuparuk Oil Pool 11290 feet Plugs 6669 feet 11185 feet Junk 6660 feet Size Measured Depth True vertical Depth 16" 129Sx ~ 121' 121' 7-5/8" 393 65 Sx AS I, & 410 4887' 4091' G 4-1/2" 11 175' 6661' Perforation depth: measured true vertical Tubing (size, grade, and measured depth ~d open hole f~ 11175' - 11290'; 91 - 9450'; 9675'- 10171'; 10345'- 10470'; 10685'- 10855'; 10915'- 10930'; 10960'- 11060'. ho~ ~6661'-6669~ 6637'-6651'; 6656'-6669'; 6683'-6688'; 6687'-6677'; 6673'-6672'; 6671'-6666'. 4-1/2", 12.6#, L-80 Tbg O 4677' MD. Packers & SSSV (type & measured ( BAKER 'SABLM/ZXP' Packer {~ 4677' MD. CAMCO 'DB' Nipple SSSV ~ 524' MD. 13. Attachments Desc summary of proposal __X Detailed operations program BOP sketch ~X 14. Estimated date for )eration March 19, 2001 16. If proposal was verbally approved Name of approver Tom Maunder 03/19/01 Date approved 15. Status of well classification as: Oil __ Service Water Iniector Suspended_ Signed ~'-~"~"~'~"' Title: PAl CTD Engineer Dan Venhaus FOR COMMISSION USE ONLY Questions? Call Dan Venhaus ~ 263-4372. Date March 21,2001 Prepared by Paul Rauf 564-5799 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test m Location clearance _ Mechanical Integrity Test _ Subsequent form required 10- Approved by order of the Commission Commissioner Approval no. ~O/. (:::~& Z.,/ I%EL, EIv C~ MAP , 1 2001 Form 10-403 Rev 06/15/88 · Alaska 0il & Gas Cons. Anchorage SUBMIT IN TRIPLICATE bp (" BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 21, 2001 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7t~ Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Tom: Re: 3K-22Ai Operations Shutdown (Permit # 200-026): More bad news! Nordic 1 has been unsuccessful on the 3K-22A extension (PTD#200-026). We encountered a shale just outside of the float equipment and drilled approximately 100' of it. The new hole collapsed after a wiper trip and we have failed to get back the 100'. Every short trip required re-drilling the shale. The last tag was 10' outside the shoe @ 11185'- no chance of getting a liner in the extended hole. The well has been swapped to seawater with diesel freeze protect and Nordic 1 is preparing to rig down. We are'requesting a shutdown of operations. If you have any questions concerning this revision, please don't hesitate to call me at 263-4372 or E-mail me at dvenhaus @ppco.com or venhaude@bp.com. Dan Venhaus PAI CTD Engineer RFCIFIVF. D MAR 2 ZO0'i Subject: Re: CTD BOP stack for KRU wells Date: Wed, 27 Sci(' 30 14:37:12-0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> ' Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Johnson, Mark O" <JohnsoMO~bp.com> Mark, I re-read your original E-mail. We accept these changes for the 5 wells you listed. Thanks for including the PTD numbers. That makes our life. a little easier. Thanks, Blair Wondzell, 9/27/00. "Johnson, Mark 0" wrote: Blair, I could not save the visio drawing in xls, pdf, or txt. I saved it in jpg which I think you will be able to open. I also faxed over a copy. Thx MOJ 240-8034 Good Morning Mark, We can read the attached vsd file. Can you please Send it in xls, pdf, . doc, .txt. or a paint brush file or fac to me at 276-7542 or both. Thanks, Blair Wondzell "Johnson, Mark 0" wrote: > Blair, > > We would like to make a change to the BOP stack configuration 'in five (5) > KRU CTD drilling permits. The drilling permits were approved by AOGCC in > 3/00. Please approve this change for those drilling permits listed below. > > A drawing of the proposed BOP stack is attached. > > The primary difference in this stack compared to what is in the KRU drilling > permits is how the ram type BOPs stack up. We want to put the 2" coil > tubing pipe rams below the mud cross. In the unlikely event of a mud cross > leak, this configuration would allow us to isolate the leak by closing the > pipe rams on the coiled tubing during the drilling phase. > > A risk assessment was performed on this BOP configuration and results were > fa vorabl e. > > The five sidetrack wells will be drilled 'with CTD using the dynamically > overbalanced drilling technique, as per the permits. The wells and approved > drilling permit numbers are as follows: > > Well Permit '# > 1R-O3Ai 200-021 > 3K-22Ai 200-026 > 3H-iOAi 200-041 > 3H-14A 200-020 3H-16A 200-022 <<KRU BOP Stack. vsd>> FYI, a new drilling permit request for the sidetrack of 1R-O1Bi will also include this BOP stack. Thanks, Mark O. Johnson 564-5666 (office), 240-8034 (cell) > > Name: KRU BOP Stack. vsd > > KRU BOP Stack. vsd Type: > appl i ca tion/x-unknown -con ten t- type-vsd_a u to file C:\Transfer~RU BOP Stack jpg.jpg (local) - Microsotl Intemet Explorer Page 1 of 1 KRU..C:TD::BOP :Detail 'M'bthanol :lnjec~tion · ~.t~s:':7, .~LA..,Oumk .~u'onnect:': ~' '~' iC..T IN:e.~.t:o'r' Hm ................................... ~ 'Stuffing:Box(pac.k:Off), 1:.o.','oo0 7;" Riser .Apnui~ir~ Bop :(H:yd:.ril).;7~.i/i::67! ;ID :500.0, :ps:'i.'wOrl~in g 7;~:i:t.1..6. :dDt; :5000..; p.'..s'i ~w.o~king: ipres' sure ...... f,'i'a'n'O~ d'iF'ir'e:'Re~i'~t;a'i~t:' :HCR' ': iKOlyHJ) J~:e':.to :D~ ~1~ c.:';l~oi~g:laa':n ' ' .,, . , ,, P I ' : I I ' I ,i ' I I i : ,II I ' 'i I II I I ' i I i i i' I I,Ii'..... g-.:1.'f.1.6 '.ID~ :5000 si.woTkmg pressur '!'-i' ': ,... .... ', ..':P: .............. :",' .:', ' R.a'm:.Type Dual:.Gat~: BOPE ' : iManu~il"~'b~e~ ffy;draUliC :. X.'O:$p.e.OI.',3 :.:1:~: .x~ 7.: ::.er,:'.a,.$.::: . . ......... , I. :ilMa~u8'l, valvss '. ...... ' ' ",'~ ........ ..Kill'line ~heck~¥elve ..... "Sii~g!'.'.e...o'r...D.. ~ ~ b!e:' ::Man:a'~il.:M~s:te~..Val~e~,' ;9':~e~' An"nulu. s: 9/27/00 2:26:24 PM i. ALASI~A OIL AND GAS CONSERVATION CO~ISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Bruce E. Smith, P.E. AAI Coiled Tubing Drilling Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk Unit 3K-22Ai ARCO Alaska, Inc. Permit No: 200-026 Sur. Loc. 3905'FNL, 4962'FEL, Sec. 35, TI3N, R9E, UM Btmhole Loc. 516'FNL, 2317'FEL, Sec. 26, TI3N, R9E, UM Dear Mr. Smith: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrili does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours)of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P.E. Chair BY ORDER OF THEOEOMMISSION DATED this 2:~ ~ day of March, 2000 dlffEnclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: DrillDRed.,,l l Ilb. Type of well. Exploratory D Stratigl'aphicTestl~l Development Oil l"""l Re-entry D Deepen r""lI Service I~1 Development Gas I"""1 Single Zone r~i Multiple zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 75 feet 3. Address 6. Property Designation Kuparuk Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25519 / ALK 2555 Kuparuk Oil Pool 4. Locatlen of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.0251) 3905' FNL, 4962' FEL, Sec. 35, T13N, RgE, UM Kuparuk Unit Statewide At top of productive Interval 8. Well number Number 36.3~' FEL SEC. T13N, RgE, UM 3K-22Ai #U-630610 4705' FNL, : _,_.. 26, At total depth "~'~3/~ 9. Approximate spud date Amount 516' FNL, 2317' FEL, Sec 26, T13N, R9E, UM April 21,2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD) ADL 25514, 516' O TD feetI No Close Approach feet 2560 12687 MD / 6715 TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 2O AAC 25.035 (e)(2)) Kickoff depth: 11175' MD Maximum hole angle 94° Maximum surface 3660 psi~ At total depth (TVD) 4324 psi~l O 6621' 18. Casing program Settln~l Depth size Specifications Top Bottom Quantib/of Cement Hole Casin~l Wel~lht Grade CoupIin~l Len~h MD TVD MD TVD (include sta~le data) 3-3/4" 2-7/8' 6.4 L-80 FL4S 1_._687' 11000' .659~ 12687' 6715' uncemented slotted liner 19. TO be completed for Redrill, Re-ently, and Deepen OperatbA~.s~lll~ Present well condition summary~ 0~. & ~ ~ Total Depth: measured 11180 feet jll~l~Plugs (measured) Tagged PBTD ¢~ 11055' MD on 7/15/1999. true vertical 6661 feet Effective Depth: measured 11056 feet Junk (measured) true vertical 6667 feet Casing Length Size Cemented Measured depth True Vertical depth CONDUCTOR 121' 16' 129 Sx AS I 121' 121' SUR. CASING 4853' 7-5/8" 393 Sx ASLW, 65 Sx AS I, & 410 Sx Class G 4887' 4091' LINER 6498' 4-1/2' 600 Sx Class G 11175' 6661' O, ISiIVAL Perforation doplh: ~asured ~1~5' -~4~0'; ~675' - 10171'; 10a4~' - 10470'; 10665' - 10~,$'; 10~15' - 10~a0'; 10~60' - 11060', Drilling fluid program Tirne vs depth plot D Refraction analysis D Seabed report D 20 AAC 25.050 requirements [~] 21. I hereby certify that the foregoing is tr~i~d correct to the best of/l~Y knowledge Questions? Call Dan Kara e 263-4837. A~I Coil Tubing Drilling Supervisor Date . Comml.~ion Use On~t Permit Number _ , I APl number ~ ~ I Approval date __ _ .... I see cover letter I 50- c) 2.2-.75 7- c, I I~ ~.~ ~1~ lforotherrequl~ments Hydrogen sulfide measures Other:. ORIGINALRobert N. ChristensonSIGNED BY by order of:;;~.~ Approved by Commlseioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate KRU 3K-22Ai CT Extension and Completion Intended Procedure Objective: Mill out of existing 4-1/2" landing collar/float shoe. Directionally drill a horizontal extension from the existing horizontal wellbore. Complete with 2- 7/8" slotted liner. Intended Procedure: Mill landing collar and floats/shoe at 11175'. Drill 10' of formation and perform leak-off test to 13 ppg, 0.5 ppg above the highest anticipated equivalent mud weight. Directionally drill a 3-3/4" extension using dynamically overbalanced drilling techniques. Planned TD is -12687' md. · Run 2-7/8" slotted liner to TD. · Place on production. Drilling fluids will be injected into disposal well 1R-18. Dynamically overbalanced drilling techniques will be employed to address high reservoir pressure. Plans are to use ~ 10 ppg drilling fluid in combination with annular friction losses and applied surface pressure to maintain overbalanced reservoir conditions. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. At least two times hole volume of kill weight fluid will be on location as a contingency. Frequent monitoring and rolling of the kill weight fluid will be done to ensure proper weight distribution. RECEIVED 22. 2000 Oil & Ceas. Commiaien February 14, 2000 Kuparuk 3K-22Ai Potential Drilling Hazards POST ON RIG No H2S production is anticipated. BHP: 4324 psi @ 6621' TVD, 6500'ss (12.6 ppg EMW) estimated pressure. Reservoir frac gradient is estimated at -0.85 psi/ft or 16.3 EMW, 5630 psi Plans are to drill with less than kill-weight fluid, or dynamically overbalanced. 10 ppg mud will result in a hydrostatic pressure that is ~900 psi less than reservoir pressure. Maintain at least 1000 psi WHP for well control when not circulating. Pressure loss associated with circulating (ECD) is expected to be -1000 psi so applied WHP will not be necessary while circulating. Monitor return-line flow rate and pit volume continuously. If crude enters the pits, take all returns to an outside tank first. Have on location at least two times wellbore volume, 12.6 ppg Kill Weight Fluid. Frequent monitoring and rolling of the kill weight fluid is required to ensure proper weight distribution. Maximum anticipated WHP w/full column of gas: -3660 psi assuming 0.1 psi/ft gas gradient. However, no gas saturated intervals are anticipated. RECEIVED FEB ~?. 2000 AllleOil &GaS C~s. Comminion February 14, 2000 KRU 3 K-22A(~ .~ROPOSED CT HORIZONT~ EXTENSION No Go Nipple @ 524' 4-1/2", 12.6#, L-80 Production Tubing to Surface 4-1/2"x 7-5/8" Baker SABL Packer @ 4677' 7-5/8" Shoe @ 4887' ~ No Go Nipple @ 9101' RECEIVED 4-1/2" 12.6# Liner 2-7/8" Liner Top @ ..-11000' 2-7/8" FL4S 6.4# Slotted Liner 4-1/2" Shoe @ 11175' ~ 3-3/4" Open hole TD @ 1268; PCR 2/18/2000 ARCO Plan.xlt 6000 -.~ . ~ 6100' ,,,... · r- .+-- O- 6200· -- . ~ 6500- I-- . I V 6800- A R C 0 A 1 a s k a, I n c. · ................................ ~;.,-;,-.-~.-,.;--.;~, .................... ................................................................................................................................. ; Date p~LteJ Structure : Pad 3K Well : 5K-22A Plan, 50--029-22759--01 F~t,., .... Field ~- "nuparuK River Unit Location : North ~'-=~ope, Alaska r,~ v,~ ~t,, ~, ........................................................................ East (feet) --> 1000 12~ 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 5400 5600 3800 ..... 5K--22A T5. I-~TD.: 3x-2z,, .-..~ .~i ~:' 3K-22~~ :: KB: o,,/o~i¥'i~ / / / 9 TD .,b,l_,~q? 3K-22A T5 TO 8600 8700 8800 8900 9000 9100 9200 9.300 -~ /o 7200 73~ 7400 7500 7600 7700 7800 7900 8000 8100 8200 8300 8400 8500 Vertical Section (feet) -) Azimuth 21.00 with reference 0.00 N, 0.00 E from 5K-22 , 94.00 9000 8800 8200 8000 7800 7600 I7400 7200 fTO00 6800 RECEIVED Prepared by BH102/12/00 Company: Well: Calculation Method: Vertical Sect. Plane: Measured Depth from: biD 11127.00 11152.00 11175.0(3 11177.0(3 11195.3(3 11200.~ 11202.0(3 11227.00 11252.00 11266.64 11277.00 11300.00 11302.00 11315.00 11327.00 11352.00 11377.00 11400.00 11402.00 11427.00 11452.00 11457.65 11477.00 11500.00 111 11527.00 11577.00 11600.00 11602.00 11627.00 11652.00 11677.00 11691.80 11700.00 11702.00 11727.00 11752.00 11777.00 11800.00 11802.00 11827.00 11852.00 11877.00 11900.00 11902.00 11927.00 11952.00 11954.25 11977.00 12000.00 12002.00 12027.00 12052.00 12077.00 12100.00 12102.00 12127.00 ARCO Alaska Inc. 3K-22A Version#2 Minimum Curvature 21.00 RKB 75.30 Azi 6663.35 6662.04 6660.82 6660.72 14.73 15.01 6659.82 15.13 6659.78 16.63 18.14 19.02 6657.7(3 19.44 6657.38 20.38 6656.2(3 6656.08 21.0(3 6655.25, 21.64 6654.45 22..( 6653.02 24.3(3 6651.88 25.52 6651.11 25.63 6651.05 26.96! 6650.53 28.28 6650.31 28.58 6650.30 29.41 6650.44 30.40 6650.96 30.48 6651.02 31.55 6652.07 32.62 6653.57 33.70 6655.52 34.69 6657.73 34.78 6657.94 35.86 6650.80 36.95 6664.12 38.04 6667.89 38.69 6670.33 38.27 6671.71 38.17 6672.04 36.90 6675.97 35.63 6679.56 34.36 6682.78 33.21 6665.44 33.11 6665.65 31.85 6688.16 30.60 6690.31 29.35 6692.09 28.21 6693.41 28.11 6693.51 26.86 6694.57 25.62 6695.26 25.51 6695.30 24.14 6695.74 22.77 6696.20 22.65 6696.24 21.15 6696.77 19.65 6697.32 18.15 6597.89 16.77 6698.43 16.65 6698.48 15.15 6699.09 3K-22Av2npd.xls RECEIVED X 6588.05 531364.96 6015615.71 6586.74' 531371.21 6015639.87 6585.52 531376.96 6015662.11 6585.42 531377.46 6015664.04 6564.67 531382.04 6015681.74 6564.52 531383.23 6015686.28 6584.46 531383.74 6015688.22 6583.67 531390.49 6582.87 531397.86 6582.40 531402.46 6015750.03 6582.03 531405.84 6015759.82 6580.90 53141 6015781.44 6580.78 531414.26 6015783.32 6579.95 531418.81 6015795.47 6579.15 531423.12 6015806.64 6577.72 531432.5(3 6015829.76 6576.58 531442.42 6015852.68 6575.81 531452.02 6015873.56 6575.75 531452.88 6015875.37 6575.23 531463.86 6015897.82 6575.01 6015920.01 531478.04 6015924.99 531487.38 6015941.94 531498.73' 6015961.92 6575.72 531499.74 6015963.65 6576.77 531512.53 6015985.10 6578.27 531525.70 6016006.29 6580.22 531539.25 6016027.21 6582.43 531552.04 6016046.19 6582.64 531553.17 6016047.83 6585.50 531567.44 6016068.15 6588.82 531582.07 6016088.14 6592.59 531597.03 6016107.81 6595.03 531606.05 6016119.29 6596.41 531611.05 6016125.64 6596.74 531612.27 6016127.19 6600.67 531627.23 6016146.82 6604.26 531641.78 6016166.83 6607.48 531655.92 6016187.19 6610.14 531668.55 6016206.23 6610.35 531669.63 6016207.89 6612.86 531682.90 6016228.93 6615.01 531695.73 6616.79 531708.10 6016271.92 6618.11 531719.08 6016292.09 6618.21 531720.01 6016293.85 6619.27 531731.45 6016316.05 6619.96 531742.41 6016338.51 6620.00 531743.38 6016340.64 6620.44 531752.85 6016361.22 6620.90 531761.92 6016382.34 6620.94 531762.68 6016364.19 531771.91 6016407.42 6622.02 531780.53 601 6430.87 531788.53 6016454.55 531795.34 601 6476.51 6623.18 531795.91 6016478.42 6623.79 6016502.48 Page I of 2 3K-22Av2npd.xls i" MD 12152.0~ 12177.00 12200.00 12202.00 12227.00 12252.00 12277.00 12300.00 12302.00 12327.00 12347.76 12352.00 12377.00 12400.00 12402.00 12427.00 12477.00 12500.00 12502.00 12527.00 12552.00 12577.00 12600.00 12602.00 12627.00 12652.00 12677.00 12686.58 Azi 13.65 12.16 6700.37 10.78 6700.98 10.66 6701.04 9.16 6701.73 7.66 6702.43 6.16 6703.16 4.78 6703.84 4.66 3.16 1.92 2.17 6705.43 3.67 6706.21 5.05 6706.92 5.17 6706.98 6.67 6707.75 8.17 6708.51 9.67 6709.27 11.05 6709.96 11.17 6710.02 12.67 6710.76 14.17 6711.50 15.67 6712.22 17.05 6712.88 17.17 6712.94 18.67 6713.65 20.17 6714.35 21.67 6715.04 22.24 6715.30 X Y 6624.42 531808.79 6016526.71 6625.07 6016551.09 6625.68 531818.76 6016573.64 6625.74 531819.12 6016575.60 6626.43 531823.32 6016600.23 6627.13 531826.88 6016624.97 6627.86 531829.7g 6016649.78 531831.8g 6016672.67 6628.60 531832.05 6016674.67 6629.36 531833.66 6016699.60 6630.00 531834.49 6016720.33 6630.13 531834.63 6630.91 531835.80 6016749.52 6631.62 531837.46 6016772.45 6631.68 531837.63 6016774.44 6632.45 531640.11 6016799.30 6633.21 531 643.24 6016824.09 6633.97 531 647.02 6016848.79 6634.66 531851.07 6016871.42 6634.72 531851.44 6016873.38 6635.46 531856.51 6016897.85 6636.20 531862.21 6636.92 531868.55 6016946.34 6637.58 531874.94 6016968.42 6637.64 531875.52 6016970.34 6638.35 531883.12 6016994.14 6639.05 531891.33 6017017.74 6639.74 531900.16 6017041.11 6640.00 531903.71 6017050.01 RECEIVED Page 2 of 2 C T Drilling BOPE ~ CT Injector Head Methanol Injection Otis 7" WLA Quick Connect----- I I ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ I --" 7" Riser I I Annular BOP (Hydril),7-1/16" ID 5000 psi WP Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE ~ Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold Cutters or Combination Cutter/Blinds Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Inner Annulus [Outer Annulus RECEIVED ARCO Alaska, ]nc, ~' Kuparuk 3K-22 3K~22 AP 500292275900 /elIT2pe N. PSTD ' ' 90 ftKB SSSVType: Camco DS' Ntpp/e Drlg Cor¢~e on ~;5/5 9~ _ ~D.~1:180 fKS NO GO TUBING SUR CASING Casing String - CONDUCTOR '"" ~tem Btm Jnts Wt Grd Thd Casing String - SURFACE item B~m Jnts Wt Grd ' Thd 7 025 in SUR CASING z~887· - 2970 L-80 ,Casing String - LINER Item Btm Jnts Wt Grd Th~ 4 500 ~n L 'IER 11.175 1~60 L-80 ' N~S~T T ubing Strin(1 ~ TUBING Item ' Top ' Len Jnts Wt Grd Thd ~ 4 500in TUBING 39- 463~ 12 80' L-80 NSCT Status , F~et SPFDate .i:~e _Co(nme~t Other (plugs, egu ~ etc ) - JEWELRY Depth Type -DescrLotion 4,627' SLEEVE 'Camco CM Shdin9 Sleeve wJ Camco 'X Se ecbve Profi!e 3 8 3 3812 SLEEVE Per' Ped Per' ARCO Alaska, Inc. PRUDHOE BAY UNIT DISBURSEMENT AC~ P.O. BOX 102776 ANCHORAGE, AK 99510-2776 PAGE 1 OF 1 FEBRUARY 2, 2000 TRACE NUMBER: 225126818 · CHECK NUMBER: 225126818 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMI 300] PORCUPINE DRIVE ANCHORAGE AK 9950] AMOUNT PAID: $100.00 PAY ENTITY: 0201 VENDOR NO: N00072020221 INQUIRIES:(907) 263-442214988 (FAX) P.O. BOX 103240 ANCHORAGE, AK 99510-3240 ;hvCICE DA'.=. INVOICE NUMBER VO.;CHER GROSS AMOUNT DISCOUhT/ADJUSTMENT NET AMOUNT VR012800SDD02 'Y114POOOtSdD ii $100. O0 · .FILING'.' FEE. FC~R PERMTT TO DRILL NSK S~DET. I~.ACK. 3K.:22A ... .. :...' · .:.. '.':.~ :;:....-.. · .: ! ..'.:..'.::!..: · · '.:~ ..',. ;,, .. :.' ;,,.;;::~.. ;'. ;. ;; .- ·: ...: ....~.. y ::... :.... . · .~. · : ;;~;' ..'~ ,:...~:.:..~.~ ; · '. :'. "'" :'" F':': !!.;!"~: ":'. ': ' '": ', .:' "" i:...':., ii:'F;:.':-': ·: ...: ~,;.'; '. ~.~; :![' .... .'. :..' '.', '~. . .-......::....: .,:.:. · ..; ': .,'. ',:: :..' .'.,',C,..' 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CH!~..C.K.. ................................................... ~ .~.-,.u..I. (a- '" ', ' .".,. ..... '", . ' ............................ T'*"'''~ ......................... ' .......................................................... ~'",~"*'":'~".~,''~T''~',?,'?'~ ..................... t"T :!" :ii;!;:Z' ~dhoe'" Bay; U~ 839 ",.",:. i':.'., ii:;'.P.':iiO.. Boxi:..1027,~ , /.':' ".::::~i[¢:~A~i:hora~, ;'AK.' :i:.:: "'~'"' 0997609. ' ~i;~.....*' ....' .. ,!!. ';; "..' .,".: '~x~qcrtY.: .**.,.,'*******..too ~o~$..~'o '. The':"~.i't~t:"National Bank· of Chicago,0710 .. ,'~ . '..'.": ...... : ....... ' ' "' · · _~ ' "'::::".i ..... ?¢,'" ":'""?' ". "' .. ".." ChiCago,' Hlino:is '"" "'"'{:..;'. "" ' ..... ' ..... ".' : : .:..:i ':.. . ?.?','. :....... i.'i'...?'..'...:..::.'.;:i'...!.,.'.:,,i':i ;.? '. ; .:. '.:. "..Z:' ..... !.:;...'}',:"'.~...'.':".":.i'.:'.:.: ':.i"". , . ' ; ' 'i I .... i, i .''' i... . · II '..i i i1{:~:'I I i .... : i I .:':. I' .'' II' I ' . i ' :;..; I '' i/~- .... 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'i II ~i1'~'1 :II II II I :IIII::I I II i I r I I I i I .... .i:~II I ~ I'L .... i ii I Zl : i: ' II I ~ ' :iiII 'i':i' ~ I ' ¢ I II I i~:I :; i IIi : ' . ...:;:... ..,. ~ ., ~ .,. ...;.. ...:.: ., ., .'.'.. ,....#.: '~.,'?i?,t5 'ii ;~ BP,' i.R~!..,;:.~.BP. 3i,,,;q1:3 G .ii B. i?!~' .: .:,'~..:.~. EI.q...q~..?.~B q.:,....::,,.::. 1:.~ ...... :.:.:._. ,_ .,,~. :: it.~-"Dislsui-~e~nt':A.'cco.'"'.ant:.!.' ,' ~;:. "~' :'!{i' c;4~~. :6.;" .:'- .-:. ;',i"...i:.:.:(.:.': '.]...:',:. .' ;' .! .:: '-.'. ·: ..: ::; · '.' · i:':[...: ,::i..:'i.;'.i ;,.: 99510.-2"776.:'?.;.::'":' ;' .'".... I I ' II ZI I ~ ~ : ~ , III I[II I 'I : III I : I III I II I t :I: I; ~I I~::I ~I;' I }:'~ ~;I'I;I''; . ' · ;!...':~'.":'.'.i'":::.'.~ ". :' ::;' ' '"'.....::'. }.;:? ";..:,' .::.i ~ .';" [: FEBRUARY 2, 2000 , WELL PERMIT CHECKLIST FIELD & POOL 4./~ -- COMPANY WELL NAME/E~_ ~<-Z2/.~PROGRAM: exp ~ ADMINISTRATION 1. . 3. 4. 5. 6. 7. 8. 9. 10. 11. '' ' ' 13. ENGINE~R--~O 14. 15. ~§. 17. 18. 10. 20. 2~. 22. 23. 24. 25. ~~DATE 26. _ ~-O~ 27. 28. 29. INIT CLASS Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool,~ ................ Well located proper distance from drilling unit boundary. Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate.wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to ~.CI2s(~ I)sig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. dev ~ redrll u'/ serv V' wellbore sag ~ ann. disposal para req ~ GEOL AREA <~ ~'~__~ UNIT# ON/OFF SHORE GEOLOGY DATE ,~R Z... 2~-Z)O ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N 30. Permit can be issued w/o hydrogen sulfide measu{.es ..... 31. Data presented on potential overpressure zones~: .... ~/t 32. Seismic analysis of shallow gas zones ........... Seabed cond~bon suwey (~f off-shore) 33. " · . ............ 34. Contact name/phone for weekly progress repoffs [explo~to~ onl~ N GEOLOGY: ENGINEERING: UICIAnnular COMMISSION: Commentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 02117/00) 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 Simpl. ify' 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 inforrnatio.n. c OO*09G l l&oo **** REEL HEADER **** MWD 03/02/11 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 03/02/11 125102 01 1 3/4" TINY *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: ldwg.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block #MNEM.UNIT Data Type STRT.FT 11175.0000: STOP.FT 11290.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API. API NUMBER: ~Parameter Information Block #MNEM.UNIT Value CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value Phillips Alaska, Inc. 3K-22A Kuparuk River Unit 3905' FNL, 4962' FEL North Slope Alaska Baker Hughes INTEQ TINY - Gamma Ray 18-Mar-01 500292275901 Description SECT. 35 TOWN.N 13N RANG. 9E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 75.3 DMF . KB EKB .F 75.3 EDF .F N/A EGL .F N/A CASE.F N/A OS1 . DIRECTIONAL ~Remarks : Section : Township : Range : Permanent Datum : Elevation Of Perm. Datum : Log Measured from : Feet Above Perm. Datum : Drilling Measured From : Elevation of Kelly Bushing : Elevation of Derrick Floor : Elevation of Ground Level : Casing Depth : Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data recorded while drilling. (4) Well 3K-22A was kicked off from the Well 3K-22 at 11175 ft MD (6586 ft SSTVD). (5) Well 3K-22A was drilled to a TD at 11290 ft MD (6593 ft SSTVD) on Run 2. (6) The interval from 11271 ft MD (6591 ft SSTVD) to 11290 ft MD (6593 ft SSTVD)was not logged due to sensor bit offset at TD. (7) The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control) curve as per CPA Geoscience instructions. (8) A Magnetic Declination correction of 26.28 degrees has been applied to the Directional Surveys. (9) Uphole Tie In with Sperry Sun GR from 01 May 1997. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 1 23.16 ft. 28.40 ft. 2 17.85 ft. 23.09 ft. CURVE SHIFT DATA BASELINE, MEASURED, N/A N/A EOZ END DISPLACEMENT N/A Tape Subfile: 1 Minimum record length: Maximum record length: 67 records... 10 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU -- WDFN mwd.xtf LCC 150 CN Philips Alaska, Inc. WN 3K22A FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has not been depth shifted to a PDC Log. 3. Shifting waived by CPA Geoscience. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 API 2 ROP MWD 68 1 F/HR Total Data Records: 3 Size Length 4 4 4 4 8 Tape File Start Depth = 11175.000000 Tape File End Depth = 11290.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 12 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN LCC CN WN FN COUN S TAT raw.xtf 150 Philips Alaska, Inc. 3K22A Kuparuk River Unit North Slope Alaska *** LIS COM}{ENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data contains the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM -- ODEP GRCX GRCX GRAX 0.0 ROPS ROPS ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: IF ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCX MWD 68 1 API 2 ROPS MWD 68 1 F/HR Total Data Records: 6 Size Length 4 4 4 4 Tape File Start Depth = 11175.000000 Tape File End Depth = 11290.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 15 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 03/02/11 125102 01 **** REEL TRAILER **** MWD 03/02/11 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS 2 records... 132 bytes 132 bytes DEPTH GR ROP 11175.0000 -999.2500 -999.2500 11175.5000 -999.2500 -999.2500 11200.0000 96.1720 36.3320 11290.0000 -999.2500 27.0680 Tape File Start Depth = 11175.000000 Tape File End Depth = 11290.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GRCX ROPS 11175.0000 -999.2500 -999.2500 11175.2500 -999.2500 -999.2500 11200.0000 96.1720 36.3320 11290.0000 -999.2500 27.0680 Tape File Start Depth = 11175.000000 Tape File End Depth = 11290.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS