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185-217
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 5, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 17 MGS ST 17595 17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/05/2024 17 50-733-20381-00-00 185-217-0 N SPT 5278 1852170 1500 280 285 285 280 160 370 360 360 INITAL P Josh Hunt 5/21/2024 This is the MIT-IA for a disposal well after initial injection, AIO 7.004. Short string tubing included on the report; long string tubing - 100/100/100/100. 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:MGS ST 17595 17 Inspection Date: Tubing OA Packer Depth 2 1709 1640 1615IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240522111633 BBL Pumped:4.7 BBL Returned:4.5 Friday, July 5, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 disposal well James B. Regg Digitally signed by James B. Regg Date: 2024.07.05 15:35:39 -08'00' From:Brooks, Phoebe L (OGC) To:Casey Morse Cc:Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: Pre-Injection MIT for Ba-16 and Ba-17 - AIO 7.004 Date:Wednesday, July 3, 2024 2:33:21 PM Attachments:MIT MGS 16, 17 05-21-24 Revised.xlsx MIT MGS 16, 17 05-15-24 Revised.xlsx Thanks Casey. I’ve revised the reports to include the long string tubing on the MIT MGS 16, 17 05- 21-24 report as well; I’ve revised the interval on the 05/21/24 report to include “I” (initial as this was the first report after starting injection. I also changed the interval to “0” (instead of “V” as I advised) since the Area Injection Order addresses volume restrictions, not increased test intervals, specific pressures, etc. The inspector mentioned that the other string didn’t have a certified gauge and there should be calibrated gauges on both strings. Please update your copies. Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Friday, June 21, 2024 12:52 PM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] RE: Pre-Injection MIT for Ba-16 and Ba-17 - AIO 7.004 Phoebe, Attached is the 5/15/24 MIT report with updates reflected. I also noticed that the report from 5/21/24 had similar omissions, so that corrected version is attached as well. Thank you, Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC (907) 777-8322 0LGGOH*URXQG6KRDO %DNHU 37' revised the reports %DNHU CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Some people who received this message don't often get email from casey.morse@hilcorp.com. Learn why this is important CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Sent: Friday, June 21, 2024 10:17 AM To: Casey Morse <Casey.Morse@hilcorp.com> Cc: jim.regg <jim.regg@alaska.gov> Subject: [EXTERNAL] RE: Pre-Injection MIT for Ba-16 and Ba-17 - AIO 7.004 Casey, The report can only include one value in the pressure fields so please include just the long string data for the tubing and the short string pressures in the Notes on well 17. If witness was waived, please leave the AOGCC Rep blank. Since these wells are under a variance, this also needs to be referenced in the Notes (interval Type would be “V”). The Result, Interval, and Type Test were blank on both MITs – please resubmit the report with these revisions/additions. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Thursday, May 16, 2024 3:32 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: Pre-Injection MIT for Ba-16 and Ba-17 - AIO 7.004 Please find attached the MIT report for MGS 17595 16 (Baker 16, PTD# 177-017) and MGS 17595 17 (Baker 17, PTD# 185-217). In accordance with AIO 7.004, these wells were tested prior to initiating injection associated with platform P&A activities. Thank you, Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC (907) 777-8322 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1770170 Type Inj N Tubing 180 195 195 195 Type Test P Packer TVD 5067 BBL Pump 2.8 IA 0 1661 1657 1655 Interval O Test psi 1500 BBL Return 2.5 OA 170 220 220 220 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1852170 Type Inj N Tubing 290 290 290 290 Type Test P Packer TVD 5278 BBL Pump 3.0 IA 0 1652 1594 1573 Interval O Test psi 1500 BBL Return 2.5 OA 140 340 340 340 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MIT-IA required under AIO 7.004 Long string tubing - 150/150/150/150. Notes: Notes: Hilcorp Alaska, LLC Middle Ground Shoals / Baker Platform Brad Whitten 05/15/24 Notes:MIT-IA required under AIO 7.004 Notes: Notes: Notes: MGS 17595 16 MGS 17595 17 Form 10-426 (Revised 01/2017)2024-0515_MIT_MGS_State_17595_Baker_2wells 9 9 9 9 9 9 9 9 9 -5HJJ MGS 17595 17 AIO 7.004 ~age Project Well History File C~.r Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. _/~ _~- 0~ / ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type D' Other items scannable by large scanner [] Poor Quality Originals: [] Other: OVERSIZED (Non-Scann'able) NOTES' [] Logs of various kinds Other BY: Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: .. Fotderl: 5,~3o-= I~0 + 9 ~ i~w_- Scanning PreparationFo'aer2: '- 0x 5~=~:~4~ on,,f.+ /s/ TOTAL PAGES BY: BOY BREN VINCENT SHERYL MARIA LOWELL Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: BY: Stage 2 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECiAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: X YES NO O BREN VINCENT SHERYL MARIA LOWELL DATE: fO',-~l'o,c~-/S/--¢-"'% ~ IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO ~EVE~DBREN VINCENT SHERYL MARIA LOWELL D A T E:/~)~'3/'t~)<~.,, / S / ,~,.~ ReScanned (individual page [special attention] scanning completed) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si General Notes or Comments about this file: Quality Checked (done) 10/25102Rev3 NOTScan ned.wpd 410 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,September 25,2013 TO: Jim Regg oJ / r.c8uv,,viwr </30�\3 SUBJECT: xx,cxomiuu/m/e�i�7eux / ` HILCORP ALASKA LLC 17 FROM: Jeff Turkington MGS ST 17595 17 Petroleum Inspector on: Inspector • Reviewed P./.eunmJ3^--- NON-CONFIDENTIAL Comm Well Name MGS ST 17595 17 API Well Number 50-7z3-2om|-0o-0o Inspector Name: /mzTom.n:mn Permit Number: 185-217'0 Inspection Date: 9/18/2013 Insp Num: miuxT130919110308 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well' r T 17— ' ��� w 'TVD 5278 ---eao -F- /6o, r 1590 .-� 1580 - sr ' �7� 1852170 � 1��p��oa/ SPT � � —z- /�oo��� �n � 490 ' 490 �xo__ �m'_ --� Interval OTHER p |/umn% ^^' 225 225 | 225 x225 225| _1 .-L Notes: Tubing data entered is for 3 1/2"Long string.Operator plans to inject an estimated 25 bbl/day of fluids down the long string.3 1/2"Short string pressure remained static at 367 PSIG throughout test. 1.4 bbl water to fill.Pressure loss on IA was less than 10%but afte the first 30 min.the loss remained constant.I wasn't sure whether that was.considered"a stabalizing pressure trend"for a pass,so I had them repressurize after one hour,and over the next 30 minutes the IA was, 1635(initial);1628, 1622 PSIG.The tubing and OA remained unchanged. ~' SCANNED DEC 3. 0 2013 Wednesday,September 25,2013 Page 1 of 1 • � Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Friday, October 14, 2011 7:31 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Cole, David A; Martin, J. Hal; Lambert, Steve A; Ayer, PhD M; Ross, Gary D; Quick, Mike [ASRC]; Hallett, Trudi R. Subject: 2011 Third Quarter's LTSI Well Monitoring Report Attachments: Master Well List TIO Report 2011 10 01.xls Hi Tom & Jim, Here is the third quarter's report for the LTSI wells utilizing pressure monitoring in lieu of an MIT to determine any mechanical integrity problems. The wells G -29RD, G -27, G -22 & G -5RD have been moved to this LTSI report as their downhole problems (like parted tubing) do not allow a temp survey to be run to the proper depth to confirm water entry into the perfs. As a result, they are all shut -in and will remain so for now. The An -17, An -29, Ba -16 & GPP 33 -14RD wells showed increases in the 13 3/8" annulus, but they all have leveled off lately. Ba -17, after an MIT, was used in August to disposed of some fluids collected during the well kill operations on Baker. It may be used again in October for fluids collected during a well abandonment operation. I have left this well on the LTSI well list because after this usage, the well will revert to being shut -in for the foreseeable future. All the pressures seen during the usage in August looked appropriate and the well appears to have maintained its mechanical integrity throughout the disposal operations. The general pattern of stable or slowly rising pressure trends continued this month for the Baker & Dillon wells on this list with the only other pressure anomaly related to the seasonal trend in pressures apparent in Ba -15RD. The well kill operations performed on the Dillon platform in August show up very clearly on the plots. Other than the noted issues, there doesn't appear to be any wells that show indications of any well integrity problems. Larry (J ;jig 10/14/2011 Plot Pressure vs Time - Well Ba -17 • 2000 2000 9 5/8" 13 3/8" 20" — SURF Tubing Tubing 2 1500 -- Vol --- -- ..._ -- — -- -- 1500 v N 3 0 m I m i \•••■■,..... - 1000 -- . _ _ 1000 ii 500 I ~ 500 J 0 �- . 0 - 0 0 0 0 0 0 0 0 0) 0 0 0 0 0 0 0 0 0 0 0 0 \ O O 0) '42 a0 N- r O N N (0 (0 U) N a t+) M N (V O N O O 83„°5 O O ,' +) M C") N (N N N N N N N N N N N N N N N N ((N N (`1 N N N 8 U) U (0 n CO 0) 0 (N (N C) 0 U) (0 8 2 0) 0 (�` N 2 8 U) CO r (0 0) 0 O 0 0 O 0 0 0 0 0 0 0 O 0 0 0 0 0 O 0 O 0 O 0 O Date 13 3/8" 20" TIO Report 09/21/11 400 36 700 270 700 0 08/25/11 360 36 850 850 458 Data Sheet 08/24/11 210 1660 1990 1660 2112 08/23/11 470 600 1000 600 0 07/19/11 380 36 650 140 650 Ba -17 06/22/11 380 36 675 125 675 06/01/11 380 36 700 125 700 0 05/28/11 370 35 660 140 660 INJECTION 05/25/11 380 35 665 140 665 05/24/11 380 35 665 140 665 05/23/11 380 35 665 140 665 Permit # 1852170 05/22/11 380 35 665 140 665 05/21/11 375 35 660 140 660 05/04/11 360 36 700 150 700. Sundry # 303 -053 . 04/01/11 370 34 7 0 02/03/11 550 360 32 700 150 700 01/20/11 575 360 35 700 250 700 API # 50- 733 - 20381 -00 12/17/10 610 370 35 700 260 700 11/09/10 740 400 38 800 250 800 10/31/10 0 360 38 850 260 850 04/01/2009 to 10/01/2011 10/30/10 700 350 38 850 45 850 10/29/10 620 320 38 250 250 10/28/10 410 290 0 650 0 69 10/27/10 410 300 740 264 10/26/10 500 300 38 250 927 250 303 10/25/10 553 300 38 250 1080 250 173 10/24/10 590 310 38 250 1075 250 305 10/23/10 598 320 38 1385 421 10/22/10 389 300 38 250 1947 250 645 10/21/10 600 310 38 1691 909 10/20/10 639 345 38 250 1791 250 507 10/19/10 587 310 38 250 1764 250 791 10/18/10 684 310 38 250 1349 250 47 10/17/10 550 300 38 1733 851 10/16/10 690 380 38 250 1865 250 810 10/15/10 520 310 38 250 2040 250 897 10/14/2011 8:48 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 10 01.xIs Ba -17 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 06, 2011 TO: Jim Regg P.I. Supervisor l e� z (51((1 SUBJECT: Mechanical Integrity Tests l UNION OIL CO OF CALIFORNIA 17 FROM: Matt Herrera MGS ST 17595 17 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: MGS ST 17595 17 API Well Number: 50 733 - 20381 - 00 - 00 Inspector Name: Matt Herrera , Insp Num: mitMFH110830174649 Permit Number: 185 - 217 - Inspection Date: 8/23/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i 17 ' Type Inj. N• TVD 5278 - IA 545 1525 ' 1525 1525 ' P.T.D 1852170 TypeTest SPT Test psi 1500 OA 390 500 500 500 Interval °THER P/F P Tubing 150 140 140 140 Notes: Well to be used for disposal injection of pipeline pigging returns'Well was not injecting at time of test. Tubing included is for short string; long string tubing 650/690/690/690. Tuesday, September 06, 2011 Page 1 of 1 • O O O ~ ~ SEAN PARNELL, GOVERNOR ALASSA OIL AMID l][t>•-7 333 W. 7th AVENUE, SUITE 100 COATSI~iRQA7`IO1~T COMD'IIS5IOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 REVISED ADMINISTRATIVE APPROVAL AIO 7.2 Re: The application of Union Oil Company of California to increase the volume of approved wastes from the Baker Platform for the purpose of disposal. into the stratigraphic interval authorized for enhanced recovery by Area Injection Order No. 7. Mr. Timothy Brandenburg Drilling Manager ,_ Union Oil Company of California. ^ ~ "~"' -~ ~~'~ ~~ ~' ~~~~~~'` P. O. Box 196247 Anchorage, Ak 99519-6247 RE: Baker Platform (PTD 177-017 and PTD 185-217 Request for Administrative Approval Mr. Brandenburg: The Alaska Oil and Gas Conservation Commission (Commission. or AOGCC) APPROVES Union Oil Company of California (UNOCAL)'s request to increase th Mowed disposal volume in wells MGS State 17595 16 [Ba-16] and MGS State 17595 I7 Ba-17 to 100,000 barrels as requested in your letter of August 24, 2010. Prior to beginning disposal operations, please contact the AOGCC Inspectors so that witnessed MITs may be conducted. Production and injection operations were halted on Baker Platform in June 2003 and the platform surface equipment was purged/cleaned of hydrocarbons and most of the equipment removed from the platform. Waste liquids from the purging/cleaning operation were disposed of into the producing formations in Ba-16 and Ba-17 according to AIO 7.002. Slightly in excess of 10,000 barrels of waste was injected. In 2005, the productive intervals of 5 wells were plugged with cement and 7,000 additional barrels of waste was injected. A total disposal volume of 50,000 barrels was originally authorized. Unocal is now planning to place additional, shallower plugs in those 5 wells and deep and shallow plugs in the remaining 18 wells on the platform. Union requested that the total approved waste volume be increased to 100,000 barrels. The increase in volume allows for about 1,400 barrels of waste for each deep plug and 2,500 barrels of waste for each shallow plug. When the work is completed, all well drilled from Baker Platform should be plugged back proximate to the mud line in preparation for ultimate platform removal. The fluid is expected to be primarily comprised of unfiltered inlet water, produced water, produced oil, sludge, triethyleneglycol, paraffin, asphaltenes, deck drainage due to rainfall on the platform and waste liquids from the cementing process. Area Injection Order No. 7 authorizes injection in the Northern Portion of the Middle Ground Shoal Field. Administrative Approval Mr. Timothy Brandenburg • • AIO 7.2 (Revised) September 2, 2010 Page 2 of 2 AIO 7.002 authorized pumping waste liquids into the producing intervals of Ba-16 and Ba-17. Rule 9 of Area Injection Order No. 7 allows the Commission to administratively amend any rule in the order as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. Until the enhanced recovery operations were halted, Baker Platform wells Ba-16 and Ba-17 were operated in compliance with AIO 7 and 20 AAC 25.404 and 25.412. Both wells passed MITs in July 2005 in conjunction with the original deep plugging. The portion of aquifers beneath Cook Inlet described by a '/4 mile area beyond and lying directly below the middle Ground Shoal Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c). Disposal operations in these wells will not cause waste due to the limited volume of injectant and the swept condition of the underlying reservoirs that surround these wells. Unocal's correspondence demonstrates that the proposed injection wells have mechanical integrity, and that injection of non-hazardous Class II fluids into strata authorized for enhanced recovery injection by AIO No. 7 will not result in an increased risk of fluid movement into an underground source of drinking water. Pursuant to Rule 9 of Area Injection Order No. 7, the authorized total disposal volume for the we11 plugging project on Baker Platform is increased 100,000 barrels. Witnessed MITs should be conducted prior to emp g t wells for disp~ °`~° "~-.~ti, , C DONE at Anchorage, Alaska and dated September 2, 2010. ~ '` -~- ~ .~ a fa i ~ ~.~~ Daniel T. Se mount, Jr. o K. N an r,~ t,r ,~. Y... Chair, Commissioner o loner ~ '` ,.~, , 6 . AND APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • ! Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com August 24, 2010 Daniel T. Seamount, Jr. Chair , ~ ~- ~ 2 Q 1 ~' Alaska Oil & Gas Conservation Commission 333 W. 7`" Avenue t :%. = ~; ° ~~:;" ~`~~ ~~~i11S$IOCi Anchorage, Alaska 99501 ;irs;~F;f~~ Re: Baker Platform :Area Injection Order Administrative approva17.2 Dear Mr. Seamount, Union Oil are moving towards performing well P&A's on the Baker and Dillon installations. The Alaska Oil & Gas Conservation Commission authorized the injection of 50,000 barrels of Class II non-hazardous fluids on the Baker Platform, under Area Injection Order Administrative approval 7.2 (AIO 7.2), dated March 19, 2003. Currently, there has been 17,127 bbls (10,400 bbls in Ba- 16 and 6,727 bbls in Ba-17) injected, with 32,873 bbls remaining on AIO 7.2. With planning for circulating well operations underway on the 25 wells on the Baker platform and operations expected to commence October 2010, Union Oil respectfully request that AIO 7.2 be amended, to an increased disposal limit of 100,000 barrels. This will facilitate operational requirements for circulation and abandonment fluids during the Baker well P&A operations. If you have any questions or would like to discuss this matter, please do not hesitate to contact Nigel Bonnett at 263-7853 or myself at 263-7657. Sincerely, C~_-®~C Timothy C. Branden g Drilling Manager TB:sk Cc: Darrell Hammons Larry Greenstein Union Oil Company of California / A Chevron Company Re: DIsposal Danny, After talking to our engineer, these 4 wells (MGS 12, 14, 16 &17) are not disposal wells, they remain water injection that can injection special fluids down they into an oil pool. There was NO Disposal Injection Order written for these wells. The field & pool code doesn't need changed or the type of fluid on the monthly injection report 10-406. Sorry for all the confusion and MGS 14 will be changed back to a oil well. There has been no injection of any type into Well MGS - 14. If this well is tobe use for injection, a 10-403 needs submitted to convert the well. Steve :j'Ck1!~~èD " (~ ..;. Iv Shehata, Danny wrote: Steve, \Vhen did it change? Can you please send me paperwork on this well changing the field and pool? Everything I have suggests this well should be reported in field and pool 524114. The only well I see in the AOGCC database assigned to f&p 524018 is api 5073310076. A MGS well, 09, that appears to have been P&A'd back on 9/3/1976. Dam1Y From: McMains, Stephen E -AOGCC Sent: Friday, March 31, 2006 2:27 PM To: Shehata, Danny Subject: Re: Disposal You have the wrong pool code for the well. should be 524018. steve Shehata, Danny wrote: Steve, These should work. Danny Shehata Production Accountant - Gas Union Oil Company of California P: (907) 263-7617 F: (907) 263-7607 90r:I.l.Yf3~;c::.0:"":YE<:)P:~c::?tl1 -----Original Message----- From: McMains, Stephen E -AOGCC Sent: Friday, March 31, 2006 10:12 AM To: Don Page Cc: janet dormady; Danny Shehata Subject: Disposal lof2 4/12/2006 8:56 AM Re: DIsposal e e Don, A disposal order was written for 2 wells on the Dillion Platform, SMGS - 12 and SMGS - 14. January thru April 2003, there was 7,912 bbls of water injected into well SMGS - 12. This volume for the 4 months was submitted as water injection on the 10-406 and not as disposal volumes. Could someone follow-up and check this out with an engineer? If revision are needed please forward to me, thanks. Steve 200301 12L 73320126005524114900000000046500000003 000000000000139400000000IPOOOOOOOOOOOOOOOOOOOOOOOO 200302 12L 73320126005524114900000000021700000019 000000000000412300000000IPOOOOOOOOOOOOOOOOOOOOOOOO 200303 12L 73320126005524114900000000017100000013 000000000000222400000000IPOOOOOOOOOOOOOOOOOOOOOOOO 200304 12 73320126005524114900000000005700000003 000000000000017100000000IPOOOOOOOOOOOOOOOOOOOOOOOO 20f2 4/12/2006 8:56 AM ) ) Chevron III Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com Commissioner John Norman Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Baker Platform Pilot Pre-Abandonment Work Summary If'') Th,\n\ij () ß '2.Ut\!) Sç~~~E~) W~U October 10, 2005 it35-d-1J (31+'- t 7 Dear Commissioner Norman, This letter is intended to update the Alaska Oil and Gas Conservation Commission on the status of Unocal's pilot pre-abandonment work on the Baker Platform in Cook Inlet, Alaska. On October 22, 2004, Unocal proposed that a pilot program be initiated on the Baker platform to develop a safe, cost effective, and optimal method for the abandonment of multiple well bores. As noted in the letter of October 22, 2004, Unocal has operated the Baker and Dillon Platforms under a "lighthouse" mode where all oil and gas production has been shut-in. The Dillon Platform was shut-in December 2002 and the Baker Platform was shut-in August 2003. Unocal commenced the pilot study with a diagnostic program on five water injection wells and three oil wells on the Baker Platform in July 2005. The diagnostic program consisted of pressure and temperature surveys for baseline data, mechanical integrity of the completion, injectivity tests to the formation, and pressure measurement on the outer casing annuli. The injection wells initially surveyed were Baker 7, 8rd, 12, 15rd, and 27. The oil wells surveyed were Baker 13, 28, and 30. Unocal did not anticipate that any of the oil wells on the Baker platform would have a bottom hole pressure (BlIP) gradient exceeding seawater. However, when it was discovered that Baker well 28 had a static BlIP of9.0 ppg, the diagnostic program was expanded to include all of the oil wells and water injection wells on the Baker Platform as well as six wells on the Dillon Platform. The Baker water injection wells have mostly held their residual pressure since being shut-in. Their BHP gradients range from 5.8 to 9.4 ppg. Three oil wells on the Baker platform have BHP gradients that exceed a seawater gradient. Two additional wells have pressures that exceed an oil gradient but are below a seawater gradient. Under the right conditions, these wells could be capable of unassisted flow. The Baker Platform Well BlIP Summary is attached. The Dillon well BHPs are all below a seawater gradient of 8.4 ppg. No additional diagnostic well work on the Dillon platform has been initiated. ~~Jf'. .~. t'r ATE ", ~-' ~\ <.~ f-\ \ Union Oil Company of California / A Chevron Company http://www.chevron.com ) ) Commissioner John Norman Alaska Oil & Gas Conservation Commission October 10, 2005 Page 2 No temperature anomalies were noted on the Baker platform with the exception of Baker well 28. Baker 28 exhibited a temperature anomaly at approximately 5,000 feet MD, as noted on the attached Baker Composite Temperature Chart. An assessment of Baker 28 is attached with the recommendation of no remedial activity. Chevron intends to conduct annual temperature/pressure surveys on Baker 28 to monitor the well status. There were no temperature anomalies noted on the Dillon platform wells. The pilot abandonment program commenced with plugging perforations on the water injection wells initially identified (i.e. Baker wells 7, 8rd, 12, 15rd, and 27). The plugging of the perforations received Sundry approval and the integrity testing of the cement plugs was witnessed by an AOGCC representative. In addition, perforations were plugged in the water supply well Baker 501 and in the gas well Baker 32. In light of the Chevron Corporation acquisition ofUnocal, the well plugging operations for the oil wells on the Baker platform has been omitted from the 2005 pilot program to allow time to reassess economic potential under Chevron's criteria. Furthermore, the gas potential from the Baker is also being re-assessed. To better prepare for the winter, Chevron will be applying heat on both the Baker and Dillon platforms. In addition, the wells capable of receiving a freeze protect fluid in their respective annuli will be freeze protected. If you have any questions or concerns, please contact me at 907-263 -7657. Sincerely, <2-øé_¿~ ~ Timothy C. Brandenburg Drilling Manager Attachments Cc: Dale Haines Gary Eller Union Oil Company of California / A Chevron Company http://www.chevron.com Baker Platform Well BHP Summary Last Updated: October 7,2005 Pressure Survey Measured Gradient Equivalent Mud Well Well Type Date MD (ft) TVD (ft) BHP (psia) (psi/ft) Weight (ppg) Notes Ba-4 Injector 27 -Jul-05 7850 7843 3141 0.400 7.7 Ba-5 Producer 30-Jul-05 6284 5566 2753 0.495 9.5 Ba-6 Producer 20-Jul-05 5712 5709 2811 0.492 9.5 Ba-7 Injector 7 -Jul-05 6244 5630 2712 0.482 9.3 Ba-8rd Injector 7 -Jul-05 7100 6937 3288 0.474 9.1 Ba-9rd2 Injector Perfs cemented, no survey planned Ba-11 Producer 21-Jul-05 8379 8113 3273 0.403 7.8 Ba-12s Injector 6..Jul-05 Ba-121 Injector 16-Jul-05 7121 6106 2941 0.482 9.3 Ba-13 Producer 6-Jul-05 7916 7661 3236 0.422 8.1 Ba-14 Gas No survey Ba-15rd Injector 5-Jul-05 6480 6286 3050 0.485 9.3 Ba-16 Injector No survey --7'Ba-17 Injector No survey Ba-18 Gas No survey Ba-20 Producer 28-Jul-05 4134 4030 1242 0.308 5.9 Obstruction in tubing at 4139' Ba-23 Injector 23-Jul-05 8841 8499 2584 0.304 5.8 Ba-25rd Producer 22-Jul-05 9495 9033 3208 0.355 6.8 Ba-27 Injector 6-Jul-05 7779 5999 2928 0.488 9.4 Ba-28 Producer 3-Jul-05 8441 5308 2497 0.470 9.0 Ba-29 Producer 28-Jul-05 7923 7594 2165 0.285 5.5 Ba-30 Producer 4-Jul-05 10966 9109 3593 0.394 7.6 -' Ba-31 Producer 29-Jul-05 11433 10636 3795 0.357 6.9 Ba-32 Producer No survey MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg Q P.I. Supervisor ~~1 7fz-'iJ105" DATE: Wednesday, July 27,2005 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA 17 MGS ST 1759517 /"" \ %§/;t-\ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ ~ Comm NON-CONFIDENTIAL Well Name: MGS ST 17595 17 Insp Num: mitCS050722154106 Rei Insp Num: API Well Number: 50-733-20381-00-00 Permit Number: 185-217-0 Inspector Name: Chuck Scheve Inspection Date: 7/12/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 17 ¡Type Inj. N TVD 5280 I IA 250 1650 1630 1630 I P.T. 1852170 !TypeTest SPT I Test psi 1320 lOA 0 0 0 0 Interval OTHER P/F P Tubing I 750 750 750 750 Notes: Test performed in preparation for use in disposal of fluids during abandonment of wells on Baker Platform SCANNED AUG 0 B 20Œj Wednesday, July 27,2005 Page 1 of 1 (Q:" 'Fù' \ ~F r¡' ,"\, ~ ìif : f I ~ .: ,I I'., \ ~ j : I " " ",'" " ì \'~, !! ,¡A,,\]I I', '\ '\~ :-:1 / 1J\ ~ 'I! ¡:;:d ,I ,. ¡ ¡( ~ \\ : I il ?'!U i ;!I" :F¡ ',j I: 'j ,[ i~1 :.JdJ'!:.J 'w :,=, ì~ ) (!I¡øo~ '~ rE~ /, /811/' i\ \, ,~l: , ¡'l~~ , (ñ) 1"11/7 /1\ :' l J" :1 'I :-:' i ,: : '\ :: ,: /I \\ \~'<\ ! iT / f J ,I \.\ ;1 :) : ,i I, i " " 'i I [I ;l U ,) "\ '\ ',' ~ \. . jJ ! ,I,,' /, ',\,~ J,.,." ;"1,"~,, , ',\ "<' I} ,I :r :1 ,ï1¡; ',\ ~i" : l\.- ,':1 'I \ nJ ) Ij ~ \ '\ ;I !I~ ~, ,.~J :~ U \~ ~:bJ '~\~~...::J ¡J 'W Jj ~U ) A"ßA.~1iA OILAlWD GAS CONSERVATION COl'DllSSION FRANK H. MURKOWSKI, GOVERNOR 333 W. PH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 July 11 2005 Ms. Laura L. Hammond Waste Management Coordinator U nocal Alaska 909 West 9th A venue Anchorage, AK 99501 ~- \\0 ~ ~c,.-\~ \'(~-o\\ \8S-~\( ~ '~~20n¡: ^I 'N'~¡E'r,'J"",' n'l, "¡ 4.: - \J.) (''''C'''A ~~ .t I ,J U " .:... I~I Dear Ms. Hammond: Unocal Alaska ("Unocal") requested by letter dated June 1, 2005 confirmation that liquid wastes developed from gas/oil gathering line cleaning and from well abandonment may be legally injected into service wells previously approved for limited disposal of Class II wastes on Middle Ground Shoal Baker ("Baker") Platform offshore Cook Inlet. Production operations ceased on Baker in June 2003 and Unocal "cleaned" the production equipment on board the platform. Prior to initiating the cleaning operations, Unocal sought administrative approval under Area Injection Order ('"AIO") 7 to dispose of liquid wastes in either of three existing enhanced recovery ("EOR") wells on the platform. Injecting wastes into an EOR well are prohibited by Commission regulations, however the Commission determined that the liquids, mostly water and oil with some detergents would not be damaging to the reservoir. AIO 7.2 issued March 23, 2003 authorized disposal of up to 50,000 barrels of liquid wastes into either Ba-16 or Ba-17. The planned "cleaning" operations were performed during July and August 2003 with a total of 10,270 barrels of waste liquid injected into Ba-16. No waste fluid has been injected into Ba-17. At this time Unocal is proposing to conduct do\vnhole plugging operations on about 8 wells on Baker and purge the subsea oil and gas gathering lines connecting Baker with XTO Platform A to the southwest. The anticipated wastes include fluids circulated from wells (filtered and unfiltered Inlet water, cement and small quantities of oil) and fluids circulated from the subsea gathering lines (unfiltered Inlet water and small quantities of oil and condensate). Some solid wastes may be generated by these operations, however Unocal is not seeking to dispose of solids on board Baker. Nor are they seeking approval to inject domestic sanitary wastes that may be generated by the crews performing the operations. The Alaska Oil and Gas Conservation Commission has completed its revie\v of your request. Liquid wastes resulting from the described well plugging and flowline cleaning operations qualify as Class II fluids and may be injected into either Ba-16 or Ba-l 7 according to AIO 7 and Administrative Approval AIO 7.2. Prior to resuming injection operations, Unocal must Ms. Laura L. Hammond July 11, 2005 Page 2 of2 confirm the conti in Rule f AI 7. ) ) integrity of the injection wells with a mechanical integrity test as outlined ~..... cc: Steve Lambe U nocal ~~ ...~ Daniel T. Seamount, Jr. Commissioner ) ) UNOCALe " Alaska Laura L. Hammond Waste Management Coordinator Unocal Alaska Tel 907.263.7898 Fax 907.263.7901 Cell 907.398.9900 E-mail Ihammond@unocal.com June 1,2005 ~;-- ~1 11 \Có RECEIVED ( . JUN 0 I 2005 Commissioner John Norman Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Alaska Oil & G~s Cons. Commisskm Anchorage Re: Description of Proposed Work On Baker Platform In 2005 and 2007 Dear Mr. Norman: The purpose of this document is to communicate to you the scope of work proposed by Unocal Alaska during 2005 and 2007 and the disposition of the associated waste streams. Attached please find "Description of Proposed Baker Platform Well and Pipeline Work and Related Waste Disposal." Mr. Tom Maunder recommended that this information be sent to you to secure your concurrence that the fluids associated with the gathering line cleaning and the well work may legally be injected into Baker Wells #16 and #17 under existing permitting and authorizations. L:., \'\'"1 -0 l'1 L--.. \ ~ 5 - ër \ 'I Thank you very much for your consideration of these matters, and please contact me at (907) 263-7898 if you would like additional information about the proposed work. Best regards, /~/11-'~ SCANNEC JUt 1 4 2005 Laura L. Hammond Attachment: 2 pages Cc: Steve Lambe Bill Britt Bill Smith Tom Maunder, AOGCC DUPLICATE Union Oil Company of California I Unocal Alaska 909 West 9th Avenue, Anchorage. Alaska 99501 http://www.unocal.com ') ) Description of Proposed Baker Platform Well and Pipeline Work and Related Waste Disposal :Purpose froject Type and Planned Timeline Waste Streams by Project and Planned Disposition The purpose of tlús document is to provide an overview of the proposed Unocal Alaska Baker Platform work scope as requested by Mr. Tom Maunder. The following is a list of the project types and the planned timeline: Year Project 2005 P & A with cement up to 10 wells 2005 Clean and abandon Baker Pipelines 2007 P & A with cement remaining wells The following table delineates the expected waste streams and their planned disposition for each type of project: Project Type P & A with cement Waste Stream Fluids Clean and abandon Baker Fluids Pipelines Clean and abandon Baker Solids ftom Production Pipelines Test Sëparator and Shaker Clean Baker Gas Pipeline Residual Trapped Gas Both Oily Burnable Solids Both Greywater Both Both Blackwater/sewage Clean Trash OUPLlCATE Disposition Inject in Well # 16 or # 17 Inject in Well # ,16 or # 17 Offsite disposal at Commercial Disposal Vendor, likely G&1 in Texas at Newpark, or contingent disposal if Unocal Alaska has a permitted Class II Disposal Well set up for G&I such as NNA #2 Vent maximum 3,900 cu ft (based on total pipeline volume) Incineration by Envirotech, Nikiski, AK NPDES Discharge or ISO Tank to Onshore Disposal by Envirotech Offsite at Septic Vendor KPB Landfill Continued on next page ) ) Description of Proposed Baker Platform Well and Pipeline Work and Related Waste Disposal, Continued Background for Baker Pipeline Cleaning Project and Information Source Only Fluids To Be Injected The following section provides the background of the Baker Pipeline Cleaning Project and the source of the information: Source: Steve Simpson President Marine Project Management, Inc. 530 West Ojai Avenue #107 Ojai, CA 93023-2471 ph. 805-640-0799 fax. 805-640-9955 steves @ mpmi.com www.mpmì.com Reportedly, the gas pipeline is filled with H2S gas, condensate, etc., and the oil line has hydrocarbon liquids and solids. A brief description of the suspension equipment setup / requirements on Baker to handle these products includes testing and pumping equipment, inlet water, pig launcher/receiver, production test separator, shaker, bins and tankage, and a PD pump to reinject fluids. Base procedures are anticipated as follows: 1) At XTO subsea manifold - Isolate pipelines from XTO A via divers closing valves. 2) From Baker - Fill the pipelines with inlet water (unfiltered), vent or flare gas, and perform. a leak test. 3) At XTO A - Dive/hot tap both lines, flush pipelines from taps to Baker. Disconnect the pipelines at manifold and tie the two pipelines together creating a loop back to Baker. 4) At Baker - Utilize inlet water to pig the pipelines clean through a production test separator with solids and fluid to shaker/tankage and to dispose of the fluids into injection wells on Baker. Only fluids will be injected into Well # 16 and Well # 17; U nocal Alaska does not plan to mobilize Grind and Inject equipment; we plan to containerize solids captured in shakers and separators and ship them off of the Platform for approved disposal. ') ~~~~! :} !Æ~!Æ~~!Æ A.IiA.~&A OILAlO) GAS CONSERVATION COMMISSION I Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 Re: Middle Ground Shoal Unit Platforms Dillon and Baker Dear Mr. Cole: ) FRANK H. MURKOWSK', GOVERNOR 333 w. -rrn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 'f/J~~q This letter confirms your conversation with Conunission Engineer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing the monitoring frequency on the 16 wells on Dillon Platform and 23 wells on Baker Platform. Production and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please fmd the Sundry Applications, which are being returned without approval~ because the relief you request needs to be sought through a different procedure. The intent. of submitting sundry notices for each well was to establish a monthly pressure and general monitoring frequency for all wells on Dillon and Baker. There is a requirement in place for some of the water injection wells that pressures and rates are to be monitored daily and reported monthly. Since the platforms are unmanned and not operating, it is not possible to obtain daily information. When operations were curtailed, a monthly monitoring frequency was established in the Plans of Development (POD) annually filed with the Division of Oil and Gas. and Unocal desires to assure that this monitoring scheme is accepted by the Commission. As noted in the conversation, changing the monitoring frequency where presently in place and establishing a monthly monitoring frequency in general is not an action that is best accomplished with multiple sundry notices. A letter application requesting the desired monitoring schedule should be made under the applicable Area Injection Orders (AlO 7 for Baker and AIO 8 for Dillon) and Conservation Orders (CO 44 and CO 54) for the platforms/unit. The Commission looks forward to receiving your letter applications. If prior monthly monitoring information has not been submitted to the Commission, that information should be llbmitted forthwith. ,~' Sincere0~ . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this _day of November, 2004 Enel. SCANNED NO\! 2; 420D4 ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMIS~ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil of California aka Unocal 1. Type of Fkquest: 3. Address: 909 West 9th Ave. Anchorage AK 99501 7. KB Elevation (ft): 79' 8. Property Designation: BAKER 11. Total Depth MD (ft): 7,232' Casing Structural Conductor Su rface Intermediate Production Liner Perforation Depth MD (ft): 5,761 to 6,800 Packers and SSSV Type: Total Depth TVD (ft): 6,923' Length 266' 630' 3,237' 7,232' Suspend U Repair well 0 Pull Tubing 0 ,I/o" /,/ Perforate U wrr U Annular Dispos. U Stimulate 0 Time E nsion 0 Other 0 Re-enter Sus nded Well 0 Monitor Frequency <. Permit to Drill Number: Development Stratigraphic 0 0 Exploratory Service. MIDDLE GRO ND SHOAL PRESENT WELL CONDITION MMARY Effective Depth MD (ft): epth TVD (ft): 6,645' Size 30" 20" 13-3/8" 9-5/8" Perforation Depth TVD (ft): 12. Attachments: Description Summary of Proposal Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 1852170 6. API Number: 50-733-20381-00 Plugs (measured): MD TVD Junk (measured): Burst Collapse Date: 17. I hereby certify that the foregoing is true and correct to Printed NJ2m ~D. Cole Signature -' I ~ /J /} ~ t{.~ 266' 630' 3,155' 6,923' Tubing Grade: 2,110 psi 3,450 psi 6,870 psi 520 psi 1,950 psi 4,760 psi 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 e best of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a re resentative may witness Plug Integrity D Other: Tubing MD (ft): LS: 5,943' SS: 5,439' 5,494 to 6,500 S: 3-1/2" 55: 3-1/2" Both 9.2#, L-80, TD5 TBG BAKER MOD "D" SUMP PKR @ 66 0', Packers and SSSV MD (ft): BAKER SC-1L PKR @ 5891' BOP Test 0 0 Service 0 Plugged WINJ 0 0 WDSPL Abandoned 0 0 27 -5ep-2004 Sundry Number: Jr,) 'f--L(b"r 0 Mechanical Integrity Test Location Clearance RBDMS 8FL NOV 2 2 2004 APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION Subsequent Form Required: Approved by: 'fo:3 Form 10-4e+-¡;{evised 12/2003 0 RIG \ NA kyOROEROF COMMISSIONER THE COMMISSION ,0 RECEIVED OCT 1 2 2004 Alaska OH & Gas Cons. Commission Anchorage Date: Submit in Duplicate • ~ ~~ ~ FRANK H. MURKOWSKI, GOVERNOR ADMINISTRATIVE APPROVAL N0.7.2 Re: The application of Union Oil Company of California to inject approved wastes from the Baker Platform for the purpose of disposal into the stratigraphic interval. authorized for enhanced recovery by Area Injection Order No. 7. Philip M. Ayer Advising Petroleum Engineer I ~ I rJ UNOCAL Corp. C~ 5 P. O. Box 196247 I Anchorage, Ak 99501 Mr. Ayer: In .correspondence dated February 18, 2003, you state that Unocal considers production operations from the Baker Platform to be uneconomic. Unocal stopped injection for enhanced recovery on October 6, 2002. Oil is still being produced, however it is likely that all platform operations will be ended before 4`f' quarter 2003 and quite possibly before the end of 2"d quarter 2003. When oil production is stopped, Unocal intends to clean the wellbores and surface equipment. It is the Commission's understanding that Unocal does not intend to resume oil production operations on this platform. Unocal estimates that up to 50,000 barrels of non-hazardous Class II fluids will be generated by cleaning operations on Baker. The fluid is expected to be primarily comprised of unfiltered inlet water, produced water, produced oil, sludge, triethyleneglycol, paraffm, asphaltenes and deck drainage due to rainfall on the platform. Unocal applied in the above referenced correspondence to dispose of these fluids into three existing injection wells (Ba-16, Ba-17 & Ba-12) on Baker Platform. Area Injection Order No. 7 authorizes injection in the Northern Portion of the Middle Ground Shoal Field. Disposal injection is authorized by this order in the upper portion of the Tyonek Formation. Currently, no wells on the Baker Platform are completed in the. disposal interval. Rule 9 of Area Injection Order No. 7 allows the Commission to administratively amend any rule in the order as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. • • Philip M. Ayer AIO 7.2 March 19, 2003 Page 2 of 2 Until the enhanced recovery operations were halted, Baker Platform wells Ba-12, Ba-16 and Ba- 17 were operated in compliance with AIO 7 and 20 AAC 25.404 and 25.412. Ba-17 has full mechanical integrity, as demonstrated by most recent MIT performed September 26, 2002, and witnessed by AOGCC Inspector Lou Grimaldi. Ba-16 has been operating as a "waivered injector" due to tubing to IA communication, although Inspector Grimaldi also witnessed an MIT on Baker 16 on September 26, 2002 and reported that the well passed. Ba-12 is a dual injector completion with injection only via the long string. Since the end of May, 1998, treated platform effluent water has been also injected into the well as approved by Sundry 398-140. Ba-12 is also of note since it is a "lease line" injector straddling the line between the Unocal property and Cross Timbers Operating Company property. Based on the pressure monitoring information it is indicated that the injected fluids are entering the intended formation. Unocal has not identified a preferred well for the disposal operations, and. considers any of the three wells acceptable. The AOGCC concurs with regard to Ba-16 and Ba-17, however given the present use of the well and its location between the operating properties waste should not be disposed into Ba-12. The portion of aquifers beneath Cook Inlet described by a '/ mile area beyond and lying directly below the middle Ground Shoal Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c). Disposal operations in these wells will not cause waste due to the limited volume of injectant and the swept condition of the underlying reservoirs that surround these wells. Unocal's correspondence demonstrates that the proposed injection wells have mechanical integrity, and that injection of non-hazardous Class II fluids into strata authorized for enhanced recovery injection by AIO No. 7 will not result in an increased risk of fluid movement into an underground source of drinking water. Pursuant to Rule 9 of Area Injection Order No. 7 Unocal is authorized to conduct disposal injection operations into the strata authorized for enhanced recovery within the MGS A, B, C, D, E, F, and G Oil Pools. The total volume authorized for disposal is 50,000 barrels. Specific approval to convert any of the candidate wells to disposal service must be requested by sundry notice. DONE in Anchorage, Alaska this 19th of March 2003. S ah ~. Palin Daniel T. Seamount, Jr Chair Commissioner ~~.~ Randy R drich Commissioner BY ORDER OF THE COMMISSION • • Middle Ground Shoal State 17595-17 (Baker 17) 185-217 303-053 Convert from Class II-R to Class II-D Unocal is planning to shut down both the Dillon and Baker platforms in Middle Ground Shoal Field. Shut down activities have nearly been completed on Dillon. Unocal is getting their paperwork together in order to be ready to begin shut down and cleaning activities on Baker. At present the exact date they plan to begin these actions is uncertain, depending on crude prices and other work necessary on the platform. Unocal has indicated they would prefer to have all necessary activities completed on Baker prior to next winter. Unocal has proposed to convert three Class II-R wells to Class II-D service. This request is similar to Unocal's proposals for two wells on Dillon. This document deals with well Baker 17. Baker 17 was converted from a production well to an injector in early 2000. Unocal satisfactorily performed the required MIT test on January 27, 2000. Lou Grimaldi witnessed an MIT on September 26, 2002. Both tests demonstrated integrity of the casing, tubing and packer. Since being converted, a total of nearly 1.5 MM bbls of seawater has been injected in support of the platform production. Unocal halted water injection in October 2002. Class II injection operations on Baker are allowed per Area Injection Order No. 7 issued September 4, 1986. This AIO is similar to AIO No. 8 for the Dillon platform. Both orders provide for injection for enhanced recovery and for disposal. Specific intervals are defined for each with the disposal interval being much shallower (2620' to 4955'} than the production interval (5300' to 9215'). The subject well is perforated in the Tyonek A zone between 5761' and 5934'. There are additional intervals open to the wellbore, however they are isolated by a bridge plug at 5955'. The production packer is set at 5537'. The present completion was run in April 1992. AIO 7, Rule 9 allows the Commission to administratively amend any rule in the order as long as sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. The similar rule in AIO 8 was employed to authorize the disposal activities on Dillon. Although this request is similar to that for Dillon, an important difference with this particular well is that the well has primary mechanical integrity most recently demonstrated in September 2002. I recommend that Unocal's approved. An administrative proceed as planned. proposal to convert Baker 17 to disposal service be approval (AA-AIO 7.2} is attached to authorize Unocal to ~2y~ Tom Maunder, PE ~t 5` ~~ Sr. Petroleum Engineer March 19, 2003 3• t`~•o3 ~'~--~ Area Injection Order No.7 ~ http://www.state.a~local/akpages/ADMIN/ogc/oindex/aio/aio7.htm STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ 3001 Porcupine Drive Anchorage, Alaska 99501-3132 Re: THE REQUEST OF AMOCO ) Area Injection Order No. 7 PRODUCTION COMPANY for ) an Area Injection Order ) Northern Portion of Middle for the portion of the ) Ground Shoal Field Middle Ground Shoal Field ) developed by Baker Platform ) September 4, 1986 IT APPEARING THAT: 1. Amoco Production Company requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within a portion of the Middle Ground Shoal Field for purposes of enhanced hydrocarbon recovery and fluid disposal. 2. Notice of an opportunity for a public hearing on August 30, 1986, was published in the Anchorage Daily News on July 31, 1986. 3. Neither a protest nor a request for a public hearing was timely filed. Accordingly the Commission will, in its discretion, issue an order without a public hearing. FINDINGS: 1. An order permitting the underground injection of fluids on an area basis, rather than for each injection well individually, provides for efficiencies in the administration and surveillance of underground fluid injection operations. 20 AAC 25.460 provides the Commission with the authority to issue an order governing underground injection operations on an area basis. 2. The portion of the Middle Ground Shoal Field developed by Amoco's platform Baker constitutes a compact "project area" which can readily be described by governmental subdivisions. Amoco is the sole operator of this Project Area. 3. The Project Area encompasses approximately the northern one-fourth (1/4) of the Middle Ground Shoal Field. The Project Area includes all existing injection wells and injection well sites planned for enhanced recovery of oil from this portion of the MGS A, B, C, D, E, F and G Oil Pools. The Project Area also includes all well sites planned for disposal by injection into shallower Tertiary strata of oil field waste fluids which may develop from the operation of this portion of the field. 4. The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the Middle Ground Shoal Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c). 5. Less stringent requirements for well construction, operation, monitoring, and reporting of injection operations may be more appropriate than would be required when injection occurs into, through or above portions of aquifers not exempted. 6. The vertical limits of injection strata and confining formations may be defined in the Pan American Petroleum Corporation State 17595 well No. 4. 7. The strata into which fluids are to be injected will accept fluids at injection pressures which are less than the fracture pressure of the injection strata and their confining formations. 8. Statewide regulations and conservation orders govern field operations except as modified by this order. 1 of 3 3/12/2003 10:39 AM Area Injection Order No.7 • http://www.state.a~local/akpages/ADMIN/ogc/oindex/aio/aio7.htm 9. To ensure that fluids injected are confined to injection strata, the mechanical integrity of injection wells should be demonstrated periodically and monitored routinely for disclosure of possible abnormalities in operating conditions. 10. Injection wells .existing on the date of this order were constructed and completed in accordance with regulations which conform to the requirement of 20 AAC 25.412. NOW, THEREFORE, IT IS ORDERED THAT the rules hereinafter set forth govern Class II underground injection operations in the following described area referred to in this order as the affected area: SEWARD MERIDIAN T9N R12W Section 19: S 1/2. Section 30: all. Section 31: all. T9N R13W Section 25: E 1 /2. Section 36: E 1 /2. Rule 1 Authorized Injection Strata for Enhanced Recovery Within the affected area, non-hazardous fluids may be injected for purposes of pressure maintenance and enhanced oil recovery into strata defined as those strata which correlate with the strata found in the Pan American Petroleum Corporation State 17595 well No. 4 between the measured depths of 5,300 feet and 9,215 feet. Rule 2 Authorized Injection Strata for Disposal Within the affected area, non-hazardous oil field fluids may be injected for the purpose of fluid disposal into strata defined as those strata which correlate with the strata found in the Pan American Petroleum Corporation State 17595 well No. 4 in the measured depth intervals of 2620 feet to 3090 feet and 4330 feet to 4955 feet. Rule 3 Fluid Injection Wells The underground injection of fluids must be: 1) through a new well that has been permitted for drilling as a service well for injection in conformance with 20 AAC 25.005; 2) through an existing well that has been approved for conversion to a service well for injection in conformance with 20 AAC 25.280; or 3) through a well that existed as a service well for injection purposes on the date of this order. Rule 4 Monitoring the Tubing/Casing Annulus Pressures The tubing/casing annulus pressure of each injection well must be checked weekly to ensure there is no leakage and that it does not exceed a pressure that will subject the casing to a hoop stress greater than 70% of the casing's minimum yield strength. Rule 5 Reporting the Tubing/Casing Annulus Pressure Variations Tubing/casing annulus pressure variations between consecutive observations need not be reported to the Commission. Rule 6 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission which ensures that the tubing/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, which ever is greater, but not to exceed a hoop stress greater than 70% of the casing's minimum yield strength, must be held for 30 minutes with no more than a 10 percent decline. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Rule 7 Well Integrity Failure 2 of 3 3/12/2003 10:39 AM Area Injection Order No.7 . http://www.state.~/local/akpages/ADMIN/ogc/oindex/aio/aio7.htm .- Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must immediately cease injection, notify the Commission, and obtain approval for corrective action.Note:Rule 7 has been amended by Administrative Approval No. 7.1. Rule 8 Plugging and Abandonment of Fluid Injection Wells An injection well located within the affected area must not be plugged or abandoned unless approved by the Commission in accordance with 20 AAC 25.105. Rule 9 Administrative Relief Upon request, the Commission may administratively amend any rule stated above as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. DONE at Anchorage, Alaska and dated September 4, 1986. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission Lonnie C. Smith, Commissioner Alaska Oil & Gas Conservation Commission W. W. Barnwell, Commissioner Alaska Oil & Gas Conservation Commission Area Infection Order Index 3 of 3 3!12/2003 10:39 AM ~ • ADMINISTRATIVE APPROVAL NO. AIO 8.3 Philip M. Ayer Advising Petroleum Engineer UNOCAL Corp. P. O. Box 196247 Anchorage, Ak 99501 Re: The application of Union Oil Company of California to inject approved wastes from the Dillon Platform for the purpose of disposal into the stratigraphic interval authorized for enhanced recovery by Area Injection Order No. 8. Dear Mr. Ayer: On January 29, 2003, Unocal was granted approval to dispose of approved wastes developed during the cleaning of the production vessels and wells on Dillon Platform into Dillon wells Di- 12 and Di-14. Please reference Administrative Approval No. AIO 8.2. Unocal has submitted sundry approval requests for the identified wells and the specific approval for Di-12, 303-021 was given on January 29, 2003. As the approval for Di-14 was processed, it was brought to the Commission's attention that "deck drainage" resulting from rain and snow falling on the platform was a fluid that might also require disposal. Rule 9 of Area Injection Order No. 8 allows the Commission to administratively amend any rule in the order as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. The Commission has previously found that storm water collected in the drain system of another platform was suitable for disposal in a Class II-D well (DIO 22.001, June 19, 2002). Unocal has previously demonstrated Dillon Platform wells Di-12 and Di-14 have mechanical integrity suitable for disposal injection operations. In this particular case, deck drainage fluids had not been specifically identified in AIO 8.2, however, the Commission did not specifically intend to exclude such fluids from the disposal authorization. Adding deck drainage to the previously approved disposal fluids in these wells will not adversely impact the reservoir or present any increased risk to the environment. The portion of aquifers beneath Cook Inlet described by a Y4 mile area beyond and lying directly below the middle Ground Shoal Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c). Philip M. Ayer ~ • AIO 8.3 March 4, 2003 Page 2 of 2 Pursuant to Rule 9 of Area Injection Order No. 8 deck drainage is an authorized fluid for disposal in Dillon Platform wells Di-12 and Di-14 within the MGS A, B, C, D, E, F, and G Oil Pools. The total volume authorized for disposal by AIO 8.2 remains 50,000 barrels. DONE in Anchorage, Alaska this 4th of March 2003. Daniel T. Seamount, Jr. Sarah Palin Commissioner Commissioner Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION • • Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7805 UNOCAL -,~~ February 18, 2003 State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Attn: Tom Maunder Baker Application for Temporary Disposal Well Ba-12, Ba-16, Ba-17 Dear Robert Crandall: Union Oil Company of California, d.b.a. Unocal, requests that Rule # 9 under Area Injection Order # 8 be used to provide the administrative relief clause to authorize temporary disposal in the Tyonek and Hemlock zones of the Middle Ground Shoal Field. Please find enclosed forms 10-403 for wells Ba-12, Ba-16 and Ba-17 and additional supportive information requesting permission for temporary disposal. All these wells were active water flood injection wells prior to shutting in the platform waterflood injection system on October 6, 2002. We are anticipating disposal of up to 50,000 barrels of fluid. If you have any questions regarding this, please contact me at 263-7620. Sincerely, a Philip M. Ayer Advising Petroleum Engineer Enclosures Aogcc MGS Baker -Application for temporary disposa1030218.doc jjd STATE OF ALASKA ~ l~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~,~~ ~~~i ~~,, APPLICATION FOR SUNDRY APPROVALS ~ ~~Sp~ 1. Type of Request: Abandon: Suspend: Operation shutdown: _ Re-enter suspended well: _ Alter casing: Repair well: Plugging: Time extension: Stimulate: _ _ _ Change approved program: Pull tubing: Variance: Perforate: Other: Temporary Disposal 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: X 79' RKB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: _ P.O. Box 196247, Anchorage, AK 99519 Service: MGS STATE 17595 4. Location of well at surface 8. Well number 1982' FNL, 481' FWL SEC 31, T9N, R12W, SM WELL #17 At top of productive interval 9. Permit number 529' FNL, 814' FWL, SEC 31, T9N, R12W, SM /~ O ~1J 8~-0~~~ ~-- At effective depth 10. APl number 420' FNL, 927' FWL, SEC 31, T9N, R12W, SM 50- 733-20381-00 At total depth 11. Field/Pool 335' FNL, 1019' FWL, SEC 31, T9N, R12W, SM MIDDLE GROUND SHOAL 12. Present well condition summary Total depth: measured 7232' feet Plugs (measured) Cmt Ret @ 6645', cmt f/ 6645'-6650',cast iron BP ~ 6650' true vertical 6923' feet Effective depth: measured 6645' feet Junk (measured) true vertical 6349' feet Casing Length Size Cemented Measured depth True vertical depth Structural 266' 30" Driven 266 266 Conductor 630' 20 1338 sx 630' 630' Surface 3237' 13-3/8" 2700 sx 3237' 3155' Intermediate Production 7232' 9-5/8" 2100 sx 7232 6923 Liner Perforation depth: measured See Attached true vertical See Attached Tubing (size, grade, and measured depth) LS: 3-1/2", 9.2#, L-8Q TDS TBG ~ 5848' TM SS: 3-1/2", 9.2#, L-80, TDS TBG ~ 5815' TM Packers and SSSV (type and measured depth) BAKER MOD "D" SUMP PKR ~ 6620', BAKER SC-1L PKR ~ 5891' 13. Attachements Description summary of proposal: Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 3/1/2003 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: Water injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Phil Ayer Signed: Titte: Advising Petroleum Engineer Date: 2/13!2003 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. Plug integrity BOP Test Location clearance '~~~=~ -r5_' Mechanical Integrity Test Subsequent form required 10-_ ~~~ ~~~~ ~ ~- Approved by order of the Commissioner Commissioner Date v ( s Form 10-403 Rev 06/15/88 ~ B D M S B F t ~ ... SUBMIT IN TRIPLICATE i • DETAIL ' . ~BING 1 A t©NG' STRING 13~3/8' 68# _ ,-3-112' 8RO x 3.1/2' TDS X0 3T - 23.112' 9.2# N-Bfl TDS TUBING @ 323T 2 g a 3.112'. x 3-112" 8R0 XO 5438' 4:. KOBE 3' TYPE'D' BHA 5439' ' Si~9$" ' ' ' XA SLEE1/,E AT ~ iS t O 6 BAKER LOCATOR SUB W/ SEALS;553T 7 ~ - C 7.OTI'S XA SLEEVE AT 5678" ;, 3 8.OTiS XA SLEEVE AT 5898'. . 313.5930' ` ' .. PROFILE 2 X 9. {7TiS 4 KOB E BHA . 10.8AKER SEALS 5943' e . SHORT STRING s ~ . _ A. 3.112" TDS x 3.1l2.8RQ XQ 3T .BAKER SC-1 '.PKR 6 ;$. 3.1/2' 9.2# N•80 TDS TUBENG` 553T 2.718' 8•RD XO 7 TDS 0~"~ x C. 3•t1 BAKER WELD SCREEN 7 A-2: !566' - 51t~~ ~ ~ Qu E E Z ~~ ~ °'~ r" . ~fr.~ ,F~"• t, a GRAVEL PACK A-3: 5763' -5782' 20-40 MESH . 8 A-4: 58GT - 5934' FRAUD W/39,000 # OTTAWA SAND 9 BAKER SC-1 PKR ~ 5947 SOTD'A-6' SAND PERFORATIONS LSOlAT10N 01SC 5955' 6027- 6052' BAKER WB.D.SCREEN ~° '8C0' ZONE INTERVALS ~~J~x~7f ` GRAVEL PAClt ~L': Bi 43' . f~ F E i /~ t o '20.40 MESH 6160'- 6230' gf~' f`8~~`. _ 8' S~ L ' . OTTAWA SAN© g 6385-:643 6454=6502'. 651.8'-6568' BAICEA SUMP PKR 8581'- 660T @ ~~ SOZPEAFS F16645.5-6647.5 CAST 1RON 8P St]ZD WfTH 200 SXS CMT @',~~ ,, 'D' ZONE 1{~RERVALS : ,6683'-6683' , 6700'= 672T 6788'- 6800: X5/8' 47 $53:5# ~ 723r ADl X7595 WELL NO.17 oRAWN: GR8 CflMpLETtON SCHE1VfAT~C sCALE: NONE UNION ~tL COMPANY 4F CAU~ORNIA {dba UNOCAL DATE: 4=6-82 • • UNOCAL ~~Alaskn Ba-17 Permit # 1852170 API # 50-733-20381-00 Packet cover sheet Ba-17.doc jjd • BAKER PLATFORM API # 50-733-20381-00 MGS ST. 17595 # 17 WELL HISTORY LAST WORK: 10/26/97 Date Finaled Work Performed 2002 10/6 Water flood system shut in. 9/26 Passed MIT 2000 ~~ 2/14 Started injection 1 /27 Passed MIT 1/25 Baseline Temperature survey and conversion to injector 1987 6/2/87 EDTA acid job and scale inhibitor squeeze. Pump 50 BBLS EDTA and 2 BBLS 4300 scale inhibitor. Displace with 180 BBLS power oil at O psi. BWO: 226 BOPD 88 BWPD 144 MCFD AWO: 274 BOPD 94 BWPD 106 MCFD 11/30/87 Replace BHA. Tag fill at 6560'. Did not clean due to low fluid level. BWO: 200 BOPD 130 BWPD 150 MCFD AWO: 216 BOPD 157 BWPD 98 MCFD 3/91 Replaced corroded tubing. Tubing failure due to corrosion caused by scale inhibitor being improperly applied via annular injection (inhibitor was not diluted). Squeezed off A-6 sand (believed to be water bearing) 6022-6052 ft. Reperforated 6092-6143', 6160-6230', 6385-6438', 6454-6502', 6518- 6568' and 6581-6607' tubing conveyed at 8 SPF. 2/92 Isolated BCD zone with bridge plug and ceramic disc (to be ruptured at a later date for comingled production. Perforated A-4 sand 5803-5936' and frac'd-with 38,000 Ibs 20/40 sand in 12#/gal GUAR fluid. Perforated A-2 sand (5665-5714') and A-3 sand (5766-5782'). Lost fluid at high rates to A-2 sand. Pumped several high viscosity pills to stop leakoff, unsuccessful. Production log confirmed A-2 sand was zone responsible for fluid loss. Set bridge plug and cement squeezed A-2 sand. Gravel packed entire remaining interval. • + A-2 sand appears to be very high reservoir quality and attempts will be made to recomplete by perforating at a later date after existing intervals are depleted. C] • DRILLING AND WORKOVER HISTORY MIDDLE GROUND SHOAL17595 WELL NO. 17 (continued) 8/92 Unable to unseat pump for routine inspection. Pulled pump with wireline. Pulled standing valve and shifted sliding sleeve to open position to allow for fluid levels to monitor production performance. Well was apparently damaged by loss of annular completion water to the formation. Production dropped almost 50% from 170 bopd @ 30% w.c. to 90 bopd at 45% water cut. Wirleine run confirmed no mechanical obstruction in well and all sleeves are open. Will monitor production for 2 months to see if waterblock will self correct. 1/93 Squeezecl 4000 gallons Xylene and water wetting surfactant. Before 50 BOPD, 150 BWPD After 30 BOPD, 150 BWPD • Middle Ground Shoal ADL 17595 WELL NO. 17 Pertinent Data: Spud Date: Completion Date January 12, 1986 Surface Location: Leg 4, Slot 7, Platform Baker 1982' FNL, 481' FWL, Sec. 31, T9N, R12W, S.M. Subsurface Location: Elevation: 79 .4' KB Total Depth: 7232' MD Plug Back Depth: 6650 ' CIBP Casing: 20" 94#, K-55 630' 13 3/8" 68#, K-55 3237' 9 5/8" 53.5# N-80 0-108' 9 5/8" 47# N-80 108-5 194' 9 5/8" 53. 5# N-80 5194-7232' Initial Potential: 636 BOPD; 127 BWPD; 288 MCFD; GOR 453 Initial Stimulation: None • • Middle Ground Shoal ADL 17595 WELL NO. 17 Perforation Record: Date Zone Interval 12-21-85 BCD 6022-6052', 6104-6130', 6162-6220', 6385-6430', 6455-6472', 6483-6500' 6519-6562', 6582-6600'. Middle Ground Shoal ADL 17595 WELL NO. 17 (Continued) Reservoir Data: Zone Depths: BCD 6022-6600' Cored Intervals: None DST Intervals • and Results: 12-19-85 Intervals 6663-6683', 6700-6727', 6788-6800'. Open 5 minutes, SI 30 minutes, open 90 min, SI 3.5 hrs. BBBL influx. Samples caught had trace oil, +-1 %. Recover 1000 cc; H 0, trace oil, .4CF gas in downhole sampler. 1231 PSI. The interval had water production and a CIBP was set at 6650'. Selective Tests: Log Inventory: 12-15-85 DIL, SP, CAL, GR CNL, CDL, GR BAKER Platform cumulative Gas Prod :3.80 MMcf ulative Oil Prod :3.32 Mbbl Cumu tive Water Prod :48.91 Mbbl 100 B-17:A Water ut o ) I 1 - - - - Wells Production J_________L________1________J_________1 I ________J_________L________ I Wells i I 1 roduction I I W ll I ti n ' s e ________________ I I .._ _ er njec o ~ ~ 1 ~ _____________J_________L________J_________L________ ~ I 1 1 I I I ________J_________L________ 1 ~ ~ I 1 ________J.________ _ I I _ 1 1 1 1 1 I 1 1 I ~ ~ 1 I I I I .___1________J_________L________J_________L________ I I I 1 ~ 1 ~ ________J_________L________ I ~ 1 I I I I I I I I ~ I I 1 1 I I 1 Cumulative Water Inj : 1292.58 Mbbl 1.0 0.8 0.6 0.4 0.2 0.0 96 92 88 84 I `JyL y:S y4 y~ y0 y~ ya ya cvvv v 1 vc ~________a________a_________r________J_________L________1________J_________L________ 10000 --------J--------- I L________1_____-__J_________L________I I I I ________1_________I 1 I 1 i---------r--------t--------~---------r---- r________r________~_ r________1 --------'--------- -------- a---------1---------'--------''---------}-------- ________~_________i 1 I I ~_________r________T________~_________r________ I I________1________J_________L________ I I 1 I I I ________ ________ ________ I L________1________J_________L________1 I l- I 1 I 1 1---------r--------T--------~- r- 1 I 1 I I I I 1 1 1 ________J_________ J_________~________i________~_________V________ 1 r________r________1_________r-_______I I I 1 1 1 I 1 1 1 I I I I I 1 1 1 1 ________J_______-_ J_________L________1________J_________L________ I r________r________y_________r________ I 1 I 1 I I 1 I ~ I 1 ~ I I 1 1 I 1 I I 1 1 1 I I I A 1 -_---1 --------i---------L-I•------1--------~---------L--------i---------~--------T---~--1 -~:-~- r-------- ,; 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10 =-______;____ Water Rate (CD) (bblld ) -----~-------------------~ --------~---------~--------- --------»---- -- Gas / Oil Ratio cf/bbl Gas Rate CD 3.81 Mcf/d Oil Rate CD 17.10 bbl, --------J---- ( ) ----------------- -------- ;---- -- Water Inj Rate (CD) (bbl/d ) -----; -------- ~---------~--------~--------~-------- --------»---- -----; ------------------!Water Cut :84.70 %--- I 1 ________J_________L .______1________J_________L________J_________L________1________~_________~________ 1 1 1 1 I 1 1 1 1 1 1 1 I 1 1 1 1 --------~---------; ~------;-------- ;---------; --------;---------; --------~IVater Inj Rate (CD) :1119.84 bbll I I I I 1 I I 1 1 1 ------ 1 1 1 1 I I 1 I ________+_________r__ r________~_________r________~________-r________r________~_________r________ 1 1 I I 1 1 1 1 I 1 I I I I 1 I 1 1 1 I 1 I I I 1 1 I 1 I I I 1 1992 93 94 95 96 97 98 99 2000 01 02 PMA B General Platform Wtrfld Prod PIot02/18/2003 13:03:53 BAKER PlafiformF~lative Gas Prod :341.89 MMcf 100 80 60 40 20 0 10000 1000 100 10 B-17:B C AND D C~ative Oil Prod :490.24 Mbbl Cumulative Water Prod :291.13 Mbbl Cumulative Water Inj :0.00 Mbbl I 1 I I I Water Cut (% ) ~ 1 I I --- Wells on Gas Pro tion Wells on 'I Pr ion 1 1 1 I I Wells on at tion ' ~ 1 1 I I 1 I ; I 1 ~ 1 ~ I ~ 1 1 ~ ~ I I I 1 I ~ ~ 1 I 1 I ~ I I I I ~ I I I ~ 1 I I I I ~ ~ I ~ ~ ~ 1 ~ I I I ~ I ~ 1 I I I 1 ~ ~ I 1 I I ~ ~ ~ ~ I I 1 I 1 ~ ~ ~ 1 1 ~ ; ~ 1 1 I I I 1 ~ 1 1 1 lyoo of o0 oy au yl ac yo av a~ yo ai yo ~a c~vv ul vc 1.0 0.8 0.6 0.4 0.2 0.0 -----;-----;-----•-----~-----~-----a-----~-----~------~-----~-----~-----~-----~----------------------- 1_____J_____J_____J_____J_____J______I I 1 1 I 1 1 1 -----r-----r-----1 1 1 I I 1 r-----r-----r-----r-----r-----r-----T-----T----- -----~-----~-----T-----T-----------------1-----T -----~-_-__~___--~-----4-----~-----i-----~-----1----_ 1 I 1_____1_____1_____J_____J_____J_ I 1 1 1 I 1 1 1 -----r-----r----_I I 1 I I 1 -----r-----r-----r-----r-----r-----r----------------- ____-1 1 1_____1_____1_____J-____J_____J___-_ 1 1 1 1 I I 1 1 r-----r-----1 1 1 I 1 1 r-----r-----r-----r-----r----------------------- 1 I 1 1 1 1 1 1 1 1 I 1 1 1 1 1 ___--v_----a_--__ ti__-__ti_____ti_____~___-_~---__~_-_--~-__-_J_____ 1 1 T-----1-----------------',-----T-----1 1 1 1 I 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 I 1 1 -----~_----1-----T-----T-----'+-----~------1-----T'-----~'-----~-----~-----~__---a-----1-----1-----J----- 1 1 1 1 I 1 1 1 1 1 1 1 1 I 1 1 1 1 I 1 1 1 I 1 1 I I I I 1 1 1 1 I I 1 1 1 I 1 1 1 1 1 I I 1 1 __---1 1 1-----1- ---J-----J-----J-----J----- I 1 1 I I 1 1 1 r-----r-----1 1 7 1 I 1 I r-----r-----r-----r-----r-----r-----T-----T----- 1 1 1 1 v 1 1 I I 1 1 1 I I 1 1 1 1 1 1 r" I 1 I 1 I I I 1 1 I 1 I 1 1 1 ( , 1 1 I I 1 1 1 I ~ ~ 11 I ~ ~ ; ; ; I I ; ; 1 1 /l~ 1 1 1 1 ` A 1 A; I/I II I ~ ~ 1 1 I 1 I 1 1 I 1 1 ----- •-- T- - T--- ,-----1--- 1-----1------~-----1------~-----~-----1-----y-----~-----y----- -----~=11===•--Lip ~..-la,---f=_,-----,---n-,-----~-----~-----~-----~-----~-----~-----~-----~-----J----- _____L _-__1_ _ _ ~___ ~__I-__a__ _ ~_____+_____L_____L_____L_____L_____L_____1_____1_____J_-___ _T J.--- _ 1 r_-___r_---_r____-r---__T_-_-_T__---T---__T---__ _111 I -1---L~ ~--YT---~ ;--I'--;--~ ~;----- ~----- I 1 1 I 1 1 1 1 --{~-----r-----I I 1 1 1 1 1 1 1 r-----r-----}-----}-----~-----1----- L_____1_____a~____J___~_J__{._AJ__1__J_____J______L_____l_____l_____L_____1_____1_____1_-___J_____ I ~ ~ I~ ~ I 1_____.-____ 1 1 1 1 1 I I -~ r _ _T_ ___T_____T____I. ~__~--~__T__1 I r_____r_____r_____r-____T_____y____-y-____y_____ I 1 1 I I 1 1 1 1 I I 1 1 1 1 1 1 1 1 1 1 I 1 I _____~ .p_ _ I____ I 1 f.__1 I r._____f-----f---_-f_____t_____y___-_y_____y_____ 1 1 T_____11__ ,____-1______1 1 I I 1 1 1 1 I 1 1 I I 1 1 I 1 1 1 1 1 1 1 1 ----_L_ 1 1 1 1 1 1 I 1 1 1 I I 1 1 -- ---•---- y---- y~----~ - -~-----~------L-----1------L-----L-----L-----1-----1-----1----_ 1 1 1 1 1 1 I 1 1 1 I I 1 1 I 1 I 1 1 1 I I 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I 1 1 1 1 1 1 1 1 1 I 1 I I I 1 1 1 1 1 I I 1 1 ._ _I .--1 _J J_ __---J___-_ 1 1 1 1 1 -- 1 1 1 r---_-1-- - 1 - I _ 1 r-----r -----r-----r-----r- ,----',-----,----- _ r_____y_____T-_ __T_ T_ ______~ _____r_____r_____r_____r_____~_____y_____y_____y_____ ___-a_----a_-_-- __-- ~- __--_ ~---__~___-_~_____~___--a_____i___--J-_-__J_____ I 1 1--_-_1--__ 1 1 1----I 1 I I----I 1 r , , ----T---- ----r-----r-----1 I I ~-- ,- ~------r-----r- r-----r-----r-----r- T-----T----- -----~-----L-----y-----y---- ~- - ~-----~------~-----~-----~-----~-----L-----1-----1---_-J----- I 1 1- I 1 1 I I 1 1 1 I I 1- 1 _____1 I 1_____1_____J__ __J_____J___-_ I 1 1 1 I 1 1 1 r-----r-----1 I I - ~- I I r-----r-----r-----r-----r-----T-----T-----T----- I 1 1 I I 1 1 I I I I I I 1 1 ---__I I 1-_---1-----J I--J__-__J-_--- 1 I I I I I I 1 r-----r-----1 I I _._ I 1 r-----r-----r-----r-----r-----r----------------- I 1 1 I ~ 1 1 1 I 1 1 I 1 1 1 1 1 1 I I i i I i I I I I I I 1 1 i i _____~_____~_ ___y____-a_____~_____~_ __1---___~_____~_____r_____ 1 1 1 1 1 1 ___ 1 I 1 1 Oil Rate (CD) bl/d ) 1 I Liquid Rate ( ) (bbl/d ) ~ ~ ~ Date: Jan-1993 ; I I I I 1 I 1 1 1 _____~=====T= Water Rate ( )(bbl/d ) ---------------------~-----=------~-----~-----~----- -----r-----T- --- Gas / Oil Rati (cf/bbl ) Gas Rate (CD) :53.57 Mcfld Oil Rate (CD) :43.94 bt -----~-----L- - --- --- --- ---- -- -----;-----~- - - - Waterlnj Rat (CD)(bbl/d )---;-----~-----~-----~------~-----------~-----~----- ------------- ---,-----~-----~-----~--Water Cut :100.00 %- I I I I 1 I 1 __-__L_____1_____1_____1_____J_____ .____J_____J______l__-__L_____L_____L_____~_____a_____~_____~_--__ 1 1 1 1 I 1 I I I I 1 I 1 1 1 I 1 1 1 I 1 I 1 I I 1 1 1 1 1 _____L_____1_____1_____J_____J_____J_____J______I______1______l_____l_____L__ • Water Inj Rate (CD) : * bbl/d I 1 1 ~ 1 1 1 1 I I 1 1 ~ 1 ~ ~ _--__r__-__T_____T_____T___--~---__~_____~__-_-T _-___r__-__r_____r_____r_____T_____T__-__T_____T_____ I I I 1 1 I 1 I I I I 1 1 I 1 1 1 1 1 1 1 I 1 1 1 I 1 1 1 I 1 1 1 1 I 1 1 1 1 1 1 I 1 1 1 I 1 1 1 1 I 1 I 1 1 I I I 1 1 I 1 1 1 1 I 1 I I 1 I 1 I I I 1 1 1 I 1 1 1 1 1 I 1 1 1 I I 1 1 1 I 1 1 1986 ' 87 88 89 90 91 92 93 94 95 96 97 98 99 ' 2000 ' 01 02 PMA B General Platform Wtrfld Prod PIot02/18/2003 13:05:50 l • D~`~6 ~~~ • ADMINISTRATIVE APPROVAL N0.8.2 Re: The application of Union Oil Company of California to inject approved wastes from the Dillon Platform for the purpose of disposal into the stratigraphic interval authorized for enhanced recovery by Area Injection Order No. 8. Philip M. Ayer Advising Petroleum Engineer UNOCAL Corp. P. O. Box 196247 Anchorage, Ak 99501 Mr. Ayer: In correspondence dated January 23, 2003 you state that Unocal considers production operations ~'- ,~,,,~o- from the Dillon Platform to no longer be economically viable. Oil production on the platform has s v~~ been shut in since December 8, 2002. Unocal intends to clean the surface equipment from ~ January through April 2003 and does not intend to resume oil production operations on this ~'?~ structure. Unocal estimates 50,000 barrels of non-hazardous Class II fluids will be generated by cleaning operations on Dillon. The fluid is expected to be primarily comprised of unfiltered inlet water, produced water, produced oil, sludge, triethyleneglycol, paraffin and asphaltenes. Unocal applied in the above referenced correspondence to dispose of these fluids into two existing Dillon Platform wells. Area Injection Order No. 8 authorizes injection in the Southern Portion of the Middle Ground Shoal Field. Disposal injection is authorized by this order in the upper portion of the Tyonek Formation. Currently no wells on the Dillon Platform are completed in the disposal interval. Rule 9 of Area Injection Order No. 8 allows the Commission to administratively amend any rule in the order as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. ~ • Philip M. Ayer r AIO 8.2 January 29, 2003 Page 2 of 2 Unocal has demonstrated Dillon Platform wells Di-12 and Di-14 have mechanical integrity suitable for disposal injection operations. Di-12 and Di-14 are respectively, a decommissioned waterflood injector and a depleted oil producer. The primary candidate for disposal operations is the Di-12 well with well Di-14 intended as a back-up. Disposal operations in these wells will not cause waste due to the limited volume of injectant and the swept or depleted condition of the u:yn~ez~c~~ reservoirs to these wells. V -f~+f svrr~...~ The portion of aquifers beneath Cook Inlet described by a '/4 mile area beyond and lying directly below the middle Ground Shoal Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c). ~,'. s-rJ Pursuant to Rule 9 of Area Injection Order No. 8 Unocal is authorized to conduct disposal S ~, injection operations in Dillon Platform wells Di-12 and Di-14 within the MGS A, B, C, D, E, F, '`A ~ and G Oil Pools. The total volume authorized for disposal is 50,000 barrels. DONE in Anchorage, Alaska this 29th of January 2003. Cammy Oechsli Taylor Daniel T. Seamount, Jr. Chair Commissioner BY ORDER OF THE COMMISSION Michael L. Bill Commissioner MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O. Taylor Chair THRU: Tom Maunder Petroleum Engineer ~~1~o~ FROM: Lou Grimaldi Petroleum Inspector NON- CONFIDENTIAL DATE: September 26, 2002 SUBJECT: Mechanical Integrity Tests UNOCAL Baker Platform Ba-4, 16, 17, 23 Middle GrOund Shoal Field Packer Depth Pretest Initial 15 Min. 30 Min. WellI Ba-4 I Typelnj. J S I T.V.D. J 4621 I Tubingl 2950 J 2950 ] 2500 I 2550 J lntervalI 4 P.T.D.I 1690090 ITypetestl P ITestpsil 1155 I CasingI 1550110501105011050I p/F I __P Notes: , Well! Ba-16 I Typelnj. I S I T.V.D. I 5067 J TubingJ 1050 I 1050 I 1040 J 1040 I lntervalJ 4 P'T'D'I 1770170,Typetestl P ITestpsil 1267 ICasingl 410 I 16~01 16~0146501P/F I P Notes: WellI Ba-17 I Typelnj.I S I T.V.D. 15280 I Tubing J 1660 J2050 J 2050 12060 I lntervall 4 '. P.TiD.I 1852170 ITypetestI P I TestpsiI 1320 ICasingI 600 11550115101150O1 P/F I P Notes: WellI Ba-23 J Typelnj.I S J T.V.D. J8212 J Tubing J3040 13050 J3050 13050 I lntervall 4 ! P.T.D.I 1840110 ITypeteSt I P I TestpsiI 2053 ICasingI 300 I 2170 I 2150 I 2140 I P/F I --P I Notes: I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I-- Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I arrived the platform and was met by Mike Lott (operator) who provided me with the well info. We tested four wells today with all passing their tests. [ toured the platform during the tests and found it to be in good condition considering the reduced personei. M.I.T.'s performed: Four Attachments: Number of Failures: None Total Time during tests: 4 hours cc: Chris Myers Steve Meyer MIT report form 5112/00 L.G. MIT MGS Baker 09-26-02 LG.xls 9/27/2002 ! U i OCAL Monthly Injection Report ........................ , , ~_m.----_-.__- ......... WATERFLOOD INJECTOR MONTHLY REPORT BAleR PLATFORM: BA 17~95' 507~20~}$100S01 Hfs Volum~ 'rbg 9,625 Csg 13.375 Csg Well Date On Injected Press Press Press ,iii till I Il I I I------ BA 17-95 12/1/00 24 2122 2150 500 40 i i BA 17-95 12/2/00 24 2118 2150 500 40 BA 1%95 12/9/00 24 2120 2150 500 40 BA 17-9:5 12/4/00 24 2119 2150 500 40 BA 17-95 1215100 24 2118 2t50 500 50 la I if---- BA 1%95 12/6/00 24 2121 21:50 500 50 III III II III BA 17-?:5 12/7/00 24 2119 21:50 500 40 BA 17-95 12/$/00 24 2114 2150 500 40 I1 I II . I ' III ~k--i ~;~5- 12/9/00 24 2112 'I 21:50 500 45 .. · BA 17-95 12/10/00 24 2111 2150 500 50 BA 1%95 12/11/00 24 2107 2150 500 50 BA 17-9:5 12112/00 24 2117 2150 500 50 · BA 17-95 I2/13/00 24 2113 2150 500 50 *i,i ii *I I .... I III BA 17-95 12/14/00 24 2108 2150 500 50 i ii, II I Il mil .......... BA l 7-95 12/15/00 24 2099 2150 500 50 BA I%95 ' " 12116/00 :~3 '2042 2150 "500 ..... 50 ..... BA 1%95 12/1'~00 24 2114 2150 ~00 50 ,limn ii i,i BA 17-98 12/18/00 24 2124 2150 500 30 BA l%95 12/19/00 24 2123 2150 ~00 30 m* ..... alii I ...... , mi BA 1%95 12/20/00 24 2129 2200 500 0 BA 1%95 12/21100 24 ' 2132 2200 500 0 mir · mm ,m BA 1%95 12/22/00 24 2116 2200 500 42 ....... iii BA 17-95 12/23/00 22 1842 2200 500 42 im~ m i iii . i i BA 1%95 t 2/24/00 23,5 2119 2150 500 42 I- __i., ,ill mi ..... I II * m BA 1%95 12/25/00 24 2125 2190 - ~00 42 -, ---- m ..... ii ii n :BA 17-95 12126/00 24, 2115 2190 500 42 BA 17-9-5 12/27/00 24 2110 2200 ~00 i_ ill , ii __ i i mm . m i BA 1%95 t 2/2~/00 24 2105 2200 500 42 ** I .......... BA 1%95 ' 12/29/00 24 2105 2200 500 42 -~"1%95 12/~0/00 24 2106 2200 5~'0 42 ~BA 17.95 -'i'2/31/00 '' 2-4 2106 " 2200 50~)'" 4i ' Y~ n~ ~' m~ber 202 ~ thi.~, websltc and tld~ p.~ h~ been hit 9 t~mc*, sine= 10F27/2000, http://kodiak,anchortown,unocal,com/Surveillance/Injector_VarianceReport.asp 1 / 1/01 Well BA l%95 17-95 ~ 1%95 1%95 17-95 BA 17-95 BA 17-95 BA 17-95 BA 17-95 BA ~ 7-95 17835 17-95 BA 17-95 BA 17-95 BA 17-95 17-95 BA 17-95 BA 17-95 BA 17-95 BA 1'/-95 ~A 17-95 BA 1%95 17-95 BA 17-95 17~5 BA 17-95 I~A 17-95 I%95 Monthly Injection Re~--'~t ]~A 1%95; ¥olume Tbg Dale l~re~s 6/1/01 1082 2100 6/2/01 2174 2200 6/5/01 2137 2200 6/4/01 2114 2200 6/5/01 2107 2200 6/6/01 2115 2200 6/7/ql 2089 2200 6/8/01 2090 2200 6/9/01 2095 2225 6/10/01 2131 2225 6/t l/0l 556 1500 6/12/01 0 1400 · 6/13/01 O 1300 6/14/01 0 1250 6/15/01 0 1200 6/16/01 0 1150 6/1'//01 0 1100 6/18/131 0 1100 6119/01 0 1050 6/20/01 0 1050 6/21/01 0 1000 6/22/01 0 1000 0 970 6/25/01 6/24/01 0 95O 6/25/01 0 950 6/26/01 0 9OO 6/27101 0 900 6/28/01 0 900 6/~9/01 0 900 17-95 6/30/01 ~ 0 900 ara u~or ~,n~I~,."r 232 On tlx;~ welg, Re arv~ fifth ,o,~ h~.~ b~o. I~ 47 ~,im,:s ~b~o0 10/27/2000, 9,6Z5 Csg 15-¥/5 l~r~s l're~ 650 10 650 20 650 20 650 25 650 25 6_50 25 650 25 650 25 675 25 700 25 800 25 850 25 900 25 900 25 900 25 900 30 950 30 950 30 950 30 950 30 950 30 950 ~0 950 30 950 30 1000 30 1000 30 1000 30 1000 30 1000 30 , t000 30 RECEIVED JUL 0 5 20t)1 Nas~ Oil.& (~as Cons. Monthly Injection ¥'?ATERFLOOD iNJECTOR MONTHLY REPORT BAKER PI, ATFORM: gA 17-95: 507332038100801 Hfs Volume Tbg 9.62~ 13.375 C~g Well Date On IaJt~,ed Pr~s Press B.A 1%95 ~/1/01 20 176g 2150 550 20 ~A 17-95 $~/01 24 2159 2200 550 20 ....... B.A 17-9~ 5/3/0 t 24 ~ 163 2200 5~0 20 ~A i 7~$ 5/4/01 24 21 ~8 2200 556' 20 · , ~, m -r ~ ........... ~X i7~ ~/~/ol 24 21~- ..... 2200 5~0 ~0- .................... .......... BA 17~3 3/6/01 24 2165 2200 S~0 20 BA 17~ 5/7~1 24 2160 2225 550 20 ..................... BA 17-9~ 5/8/01 24 21 $2 2225 550 20 i .~ 4 ii I --. i l ~ i~ ...... $~/01 " 24 215~ 222~ ~0 20 ~-is ~ .......... i _ , ~A 17~5 ~/10~1 - 24 ~ 2142 2225 550 20 BA 17~5 5112/01 24 2140 2225 5~0 20 i ~1 I I BA'17-95 5113~1 24 2130 2225 550 20 ~A 17-~ ~/14/01 24 1289 2~0 $7~ 20 ~ lg-9~ 5[1~[01 10 891 1~0 700 20 ~ 17-~5 5/16/0I 0 0 140~ 800 20 BA 17-95 5/17/01 0 0 1300 g~0 20 i ._1 ii ----. aliim ~A 17~5 5/19/01 24 2341 2100 600 20 BA 17~ 5/20/01 24 ~274 21 ~0 600 20 BA 17~5 ~1/01 24 2238 2150 700 30 ~A 17~5 5/22101 24 '21~ 2150 700 ....... 30 m m i i mm - i m BA 17~ 5~/01 24 '- 2161 2200 ~00 'BA 1%95 5/24/01 24 2153 2300 600 30 ~A 17~ 5~5/01 '-'24 21~0 2200 600 20 ~A 17-~ ' ~/26/0~ 24 2tS~ ....... 2200 600 20 ..... i I ill BA l 7~5 ~7/01 24 2148 2250 600 25 BA 17~5 5128~ 1 24 2146 2250 600 30 ,,,~ ~A 17~5 5~9/01 24 '-' 2136 ' 2250 600 30 ~ 17-95 5/30/01 ' ~ -- = ~'t ' 2 ~ ~0 22~0 600 F3A ] %95 .... ~--Bi~ 1 24 ~ 2133 2250 6~ 20 "~',~ ute u~,v ~.u~ber 571 o~ thi~,~:eb?.;tc sad Ihi.~ pa~ ha,,. be~{ hit 55 Ilme~ ~in,.,e ) 0/27/2000. RECEIVED dUN 0 2001 Alaska Oil & Gas Cons. Com~rnss~o, · Anchorage i~i,i~UNOCALiD Monthly 'Injection Report .......... ' ....... A..~.~:~--:.~. -- ....... ... ~.'; ril - .... . ., .... , ,, . ' *~' ~ ~ ' .... -. ' ~.. * - ' ---~ ' .... . ....... -~ ' ' ~ . _ ' w ,r ' ' WATERFLOOD I~JECTOR MONTHI. Y REPORT BAKER PLATFORM :BA 1%95; 507332038100S01 Well Date On ,,Injected P~ Pre~ Preg~ I ~._ I I I , , .... L ~ ~7-95 4/hot ~4 2o~s ~ 5~o .,,~ · , .i m i. I_ BA 1%95 4/2!01 24 2183 2125 525 50 iai I I MI J I I I - BA 1~95 ' 4/3/01 ~ 2160 2150 525~ 50 ~_:_' .' i Il I I- I I Ill I Ill ~1 -.Il I . . I BA 17-9~ "~/4/01 24 21 ~0 2150 525 ~0 Il a i [ BA 1%95 4/5/01 24 21 ~'" 2150 500 50 la . i ~ , I I , , "l BA 17-9~ 4/~01 23 2058' 2150 5~ . '50 la . , ..~ - I I ,1 'l · 11 BA 1%95 4/7/01' 24 2206 2175 ~00 50 BA 1%95 4/~01 24 2190 2200 - ~ 50 - , { Ill .-I I __. { I { J{ . ~ 1%95 4/9/01 24 ~199 2~0 SOO 44 ..... i all i I i i · a _ ~ III BA 17-9~ 4/10/01 21 193~ 2150 - ~0 50 ' ' I I I il .la, Ill BA I%95 4/li)01 23' 2099 2150 550 50 al Il I, · ' -- -~ I _., BA 17-99 4/12/01 24 2173 ~ 2I*S SS0 50 BA 1%95 4/13101 24 2161 217~ '550 50 · = il I I .. II ._ II I BA 1%95 4/1~01 21 1779 2100 550 BA 17-9~ ', 4/15/[1 24 1~63 " 2100 ' 550 50 , Il II ~l_ I I 2 ~ ' "' ' 1%95 4/16/01 ~ 24 1965 -'2100' 550 46 BA 1%95 4/17/01 24 1967 2100 550 46 ~ .n · ,. ~ _~l,_ ,, ~ . - · BA 1%95 - ~18/01 24 1973 2100 ~50 46 .......... b., , . ~ - - '" -~A 17-95 4t19/01 24 1969 2125 550 48 BA 17-95 4/20~0] 24 I972 . 2125 550 48 BA ~7-95' 4t21/0i .... 24TM 1~8 2125 r-- ' ~50 '-'40 ~- al lmI il i i i .. BA 17-9~ 4/~2/0~ 24 ~967 2125 550 4$ ' iii I 1. I I - _ I I il ii i Il .t I -- BA 17-95 4/23/0I 24 1961 2150 550 48 - I i l- all I I , ~.. ~A 17.95 4/24/01 22 1~49 '2150 ~50 48 BA 17-95 4/25/01 24 ..... 21 L0 2150 550 48 ~. Ill , .... I I I . 9A 17-95 '~)26/01 24 2091 21SO S~ I i i i ii ii a i i BA L%95' 4/27/01 24 2087 2150 550 -" 48 , n .-~ ~A 17-9] 4/2~01 24 2090 2170 fi~0 48 I la - ,1 i- i ~ . I I , I . ' ~ 17-95 ~30/01 24 2074 2200 550 20 : Jim Ilill .l , i Il I I ,, http ://kodiak, anchortowu, uno cal. com/Survcillance/Injcctor_VarianceReport, asp 5/I/01 r~Bp '4u- ~ DEC 01 '00 08:0E;gtM ~ . Monthly Injection Report Rcttu~ to Main WATERFLOOD INJECT,OR MONTHLY REPORT BAKER PLATFORM :BA 1%95 Hr~ Volume Tbg 9.625 Csa 13,375 Well Date On Injected Press Press Press BA 17-95 ' "I'1/1/00 24 2197 2150 600 45 ii i il · BA 17-95 11/2/00 24 2195 2150 620 45 BA 17-95 11/3/00 24 2192 2150 6~0' ' ' 45 BA 17-95 1 i/4/00 24 2187 -'2150 625 44 BA 1%95 11/5/00 24 2188 2150 620 45 I n Il In BA I%95 11/6/00 24 2177 [. 2150 600 50 BA 1%95 11/7/00 24 2176 2150 600 50 BA 17-95 11/8/00 24 2167 2150 600 BA I7-95 1 I/9/00 24 2168 2150 600 50 ................ i111 BA 17-95 11/10100 24 2161 2150 600 45 , ,.,,, · .... BA 17-95 11/11/00 24 2155 2150 600 45 BA 17-95 li7i2/00 24 2147 2150 600 35 BA 1%95 11/13100 24 2143 2150 600 40 . BA 1%95 11/14/00 24 2121 2150 575 40 BA 17-95 11/15/00 24 2153 2150 575 d0 , . n ..... ~A 17-95 11/16100 24 2154 2150 550 40 . . . BA 17-95 11/17/00 24 2156 2150 550 40 I I III II I · BA 1%95 11 / 18100 24 2169 2150 550 40 BA 1%95 11/19~00 24 2167 2150 550 40 Il I Illin I Illll BA 1%95 11/20/00 24 2169 217~ 550 40 I I I I Il --._ · BA 1%95 11/21100 2,2 1948 2175 550 40 BA 17-95 - 'i i~52/00 24 2142 2150 S~O ..... 40 BA 1%95 11/23/00 24 2152 2150 550 40 ...... . ......... ii iii BA 1%95 11/24/00 24 2146 2150 550 40 i Ti i ,. , Il -~-A-i-'7J~5 ..... 1~/25100 24 2148 2150 ~550 40 ~A 1%95 1 ]/26/00 20 1787 2100 550 40 i .I,l ........ i ...... BA 1%95 l 1/27/00 24 2149 2125 540 40 BA 1%95 11/28/00 24 2139 2150 540 40 I II II I II I BA 1%95 ! 1/29100 24 2137 2150 525 40 BA 17-95 11/30/00 24 ....... 2i25 2150 525 40 Y~ ar, ~r mlmber J064 o~ thh wobsiIe ~d th~ ps8~ [m b~a hit 40 tira~ since 10/27/2000. http://kodiak, anchortown, unocal.eom/Surveillance/Injector_VarianceReport.asp 12/1/00 Monthly Injection Report WATERFLOOD INJECTOR MONTHLY REPORT BAKER PLATFORM: BA 1%95: 507332038100S01 i II I i ii W.ll Date Hr; Volum. 4bg 9,625 C'I~ 13.375 On In jeered Press Press Press B'X 1%95 " to/l/OO 24 2237 2150 800' ' 40" BA 17-95 " 10/2/06' 24 "2235 ' 2150 ' 810 ~[ ' BA 1%95 10/3/00 24 2233 2150 810 40 BA 1%95 1014/00 24 2225 2145 800 40 BA ~7-95 i0/~/00 '24 ' 2223 2i50 800 40 ! 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Well Date On l~e~ed Brass Pr~s~ Pres~ IiSI Ill I ins ~-A 17-95 7/1/00 24 2029 2350 800 0 BX 1%95 '= 7/2/00 ' 24 2326 " 2400 800 ' 7,5 2566 2400" 78G .... o BA 17-9fi 7/~/00. ~ 24 ,. 2500 . , 2420 · 780 ;.. 40 BA 1'~-95 715/00 24 2473 2420' 750 40 BA 17-9fi 7t6/00 24 2087 2420 1900 0 I iiii I ii . _ BA 17-95 7/7/00 24 2456 2420 7~0 40 i I I II ii I i I~^ 17-95 ?/~I00 24 24~6 2400 750 40 Ill I I I II III BA 17-9~5 7/9/00 24 2510 2420 750 40 ,~, BA I7-9~ 7/10/00 24 2~00 24~0 725 40 BA 17-9'5 7/11/00 24" 2500'' 2450 "" 720 ' ~0 .., 7'-95 '7/12/00 14 .60 2450' 700 40 -- si I '! · BA 17-95 7/13/00 20J~ 2140 2400 725 40 BA 17-95 7/14/00 24 1722 2t00 725 40 _--_ · · · · Il II .... 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I ~11 i aA i 7-95 7t22/00 24 :1:500 242~ 700 50 ,·, I · i III · I i BA 1%95 7~3/00 24 2~00 2425 700 '~0 ii Il I I I al I B_A...1%95 , 7/24100, 20.5 t' 2129 .. 1900 750_ . 50 BA 17-95 7/25/00 17 , 1744 2375 750 50 II I I · i i iii BA 17-9~ 7t26/00 24 2500 2400 800 ~0 Il la a Il I I BA 17-95 7/27/00 24 2500 2400 850 50 I1 I I · I I II I I BA I%95 7/28/00 24' 2489 2400 850 50 Il I I I I I I II I BA 1%95 7/29/00 24 2500 2400 1~50 50 III t -- I I IIII I I ,,Bi '1'~-95 .... 7/30/00, [ ~ 2500 2400 875 . 50- BA 1%95" 7/31/00 24 2~00 2400 900 50 number 899 ~n thl, wab5it~ and ~Js page ba~ bhx~a .hit ,39 tJm*.~ ~iue~ 7!14,'2000 ~:23 AM. http://horn~.anchortown, unoeal, ¢om/Surveillance/Injector_VarianceReport. asp 8/4/00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: X 2. Name cf Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: X 101' RKB ABOVE MLW feet 3. Address Exploratory: 7. Unit or Property name Stratig raphic: P.O. Box 196247, Anchorage, AK 99519 Service: MGS STATE 17595 4. Location of well at surface 8. Well number 1982' FNL, 481' FWL SEC 31, T9N, R12W, SM WELL #17 At top of productive interval 9. Permit number/approval number 529' FNL, 814' FWL, SEC 31, T9N, R12W, SM 85-0217-0 At effective depth 10. APl number 420' FNL, 927' FWL, SEC 31, T9N, R12W, SM 50- 733-20381-00 At total depth 11. Field/Pool 335' FNL, 1019' FWL, SEC 31, T9N, R12W, SM MIDDLE GROUND SHOAL 12. Present well condition summary Total depth: measured 7232' feet Plugs (measured) Cmt Ret @ 6645', cmt f/6645'-6650',cast iron BP @ 6650' true vertical 6923' feet Effective depth: measured 6645' feet Junk (measured) true vertical 6349' feet Casing Length Size Cemented Measured depth True vertical depth Structural 266' 30" Driven 266 266 Conductor 630' 20 1338 sx 630' 630' Surface 3237' 13-3/8" 2700 sx 3237' 3155' Intermediate Production 7232' 9-5/8" 2100 sx 7232 6923 Liner Perforation depth: measured See Attached true vertical See Attached Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80, TDS TBG @ 5848' TM SS: 3-1/2', 9.2#, L-80, TDS TBG @ 5815'TMRECEIVED LS: Packers and SSSV (type and measured depth) BAKER MOD "D" SUMP PKR @ 6620', BAKER SC-1L PKR @ 5891' 13. Stimulation or cement squeeze summary Intervals treated (measu red) ORIGINAL AJaska 0il & Gas Cons. C0mmissi0n Anchorage Treatment description including volumes used and final pressure Conversion to injector. 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 0 0 2000 BWPD 450 2000 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: Gas: Suspended: Service: Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ~~ Title: Form 10-404 Rev 06/15/88 v' SUBMIT IN bUPLICATE .,.-. MF_.ASURED DEPTH DEPTH A-6: 6022- 6052 BCD: 6092-6143 6160-6230 6385-6438 6454-6502 6518-6568 6581-6607 6645-6647 D: 6663-6683 6700-6727 · 6788-6800 BAKER WELL #17 ADL 17595 PERFORATION RECORD DEPTH s.TATUS 5746-5775 SQUEEZED 5813-5863 OPEN 5879-5947 OPEN 6097--6149 OPEN 6164-6211 oPEN 6226-6275 OPEN 6287-6313 oPEN 6351-6353 OPEN 6397-6386 DST 64O3--6429 DST 6489--6500 DST RECEIVED ,..,...-. 1 0 2000 A~aska Oil & Gas Cons. Commission ..... Anchorage RECEIVED JAN - 9 }99~ Alaska 0~ & uas Cons. (,;omm~ss~L Anchorage Unocal Corporation Agricultural Products 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL October 26, 1999 Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Reactivation and Expansion of the Baker Waterflood Dear Blair: Due to the short economic life of oil operations in Cook Inlet and the cost to repair the waterflood facilities on the Baker platform, Unocal recently took a close look at the possibility of permanently terminating the waterflood operations on the Baker platform. After a review of the success at the Cross-Timber's A platform and realizing we could obtain variances on several wells, Unocal has decided to go forward with the reactivation and expansion of the Baker Platform waterflood. It has been down due to a series of mechanical difficulties since September 1996. The plan is to repair all the surface facilities and convert five shut-in producers to injection. No downhole modifications are planned except closing sliding sleeves and possibly perforating to improve injectivity. Three of these wells have packers and should pass conventional MIT's. The other two wells will require variances since there are no packers in the wells and the economics will not allow us to work the wells over. The variances will be based on a pair of temperature surveys before and after injection. There are no fresh water aquifers at risk and the gas reservoirs in this area of the field are either depleted or not at risk due to their location. Even if there were gas reserves in the immediate area, they would be protected through close monitoring of our injection operations which will recognize any casing/well failures. Below is a list of the conversions: B-7, B-16 and B-17 B-15RD and B-27 should pass conventional MITs. will require variances. This program has been initiated and we should be ready for injection around the end of November. This is a final effort in the life of the reservoir's main fault block to maximize the recovery of the Tyonek and Hemlock intervals which are currently near the end of their waterflood life. We expect to see response within 12 months and will probably terminate the waterflood operations permanently if no response is recognized. The facilities modifications are nearing completion and pre-injection temperature surveys are being scheduled for all the wells. Once waterflood is active in our current injectors we will run the MIT's on the first three wells, begin injection into the 5 new wells and after 30 days of injection we will rerun the temperature surveys on B-15RD and B-27 to prove casing integrity. Attachments: 10-403 Forms Wellbore Diagrams Structure/Location Map Reactivation Plans Detailed Plan for each well L~tSristo'~ Ruff Senior Reservoir Engineer Cook Inlet Waterflood Management IVED v o ~99.9 Overall Plan for waterflood reactivation on the Baker Platform 1) Repair surface piping, chemical systems, filter systems and pumps. 2) Install new control and metering systems 3) Start up waterflood in B-4, B-12L, and B-23 which are currently approved for injection. 4) Run conventional MIT's on B-7, B-16 and B-17. 5) Run temperature surveys on B-7, B-16, B-17, B-15RD and B-27. 6) Begin injection in all new wells (temporary permission to inject required on B-15RD and B-27). 7) After 30 days, rerun temperature surveys on B-15RD and B-27. 8) Obtain Variance on B-15RD and B-27 based on temperature survey results. 9) Monthly Reporting of daily monitoring on B-12, B-15RD and B-27 with reports sent to AOGCC. 10)Circulate inhibited fluid after waterflood response is recognized. 11)Shut-in operations if no response is seen after 12 months. 12)Renew Variances on B-12, B-15RD and B-27 every other year. B-7 Plan 1) Hookup permanent or temporary injection equipment. 2) Circulate out all power-oil with waterflood water, close both sliding sleeves, gauge tbg and tag bottom. 3) Run conventional MIT and obtain final approval to inject. 4) Hookup permanent injection metering and controls. 5) Inject into the Tyonek A-Zone to support B-6 production B-16 Plan l) Hookup permanent or temporary injection equipment. 2) Circulate waterflood water, close sliding sleeve, gauge tbg and tag bottom. 3) Run conventional MIT. 4) Obtain approval of MIT. 5) Hookup permanent injection metering and controls. 6) Inject into the Tyonek F-Zone to support B-11 and B-13 production. 7) If extra platform capacity exists after the full expansion is completed: Add tbg punch to allow injection into the BCD zone. Add perforations into the Tyonek A-Zone. B-17 Plan 1) Hookup permanent or temporary injection equipment. 2) Circulate out all power-oil with waterflood water and close sliding sleeve #5. 3) Tag isolation disk at 5955 MD and make sure sliding sleeves #7 & 8 are open 4) Run conventional MIT and obtain final approval to inject. 5) Hookup permanent injection metering and controls. 6) Inject into the Tyonek A-Zone to support B-5 and B-6 production B-15RD Plan 1) Run pre-injection temperature survey for baseline data, gauge tbg, and tag cement plug. 2) Hookup permanent or temporary injection equipment. 3) Circulate out all power-oil with waterflood water. 4) Verify temporary permission to inject has been granted. 5) Inject for 30 days into the Tyonek A-F zones. 6) Shut-in for 12 hours and re-run temperature survey. 7) Analyze temperature surveys to prove casing integrity. 8) Obtain variance based on temperature surveys. 9) Hookup permanent injection metering and controls. 10) Inject into the Tyonek A-F zones to support B-6 and B-I l production iVED B-27 Plan 1) Run pre-injection temperature survey for baseline data, gauge tbg and tag drillable bridge-plug. 2) Hookup permanent or temporary injection equipment. 3) Circulate out all power-oil with waterflood water. 4) Verify temporary permission to inject has been granted. 5) Inject for 30 days into the Tyonek A-D zones. 6) Shut-in for 12 hours and re-run temperature survey. 7) Analyze temperature surveys to prove casing integrity. 8) Obtain variance based on temperature surveys. 9) Hookup permanent injection metering and controls. 10) Inject into the Tyonek A-D zones to support B-5 and B-28 production STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: X 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: X 101' RKB ABOVE MLW feet 3. Address Exploratory: 7. Unit or Property name Stratigraphio: P.O. Box 196247, Anchorage, AK 99519 Service:~ MGS STATE 17595 4. Location of well at surface 8. Well number 1982' FNL, 481' FWL SEC 31, TgN, R12W, SM WELL #17 At top of productive interval 9. Permit number 529' FNL, 814' FWL, SEC 31, T9N, R12W, SM 85-0217-0 At effective depth 10. APl number 420' FNL, 927' FWL, SEC 31, T9N, R12W, SM 50- 733-20381-00 At total depth 11. Field/Pool 335' FNL, 1019' FWL, SEC 31, T9N, R12W, SM MIDDLE GROUND SHOAL 12. Present well condition summary Total depth: measured 7232' feet Plugs (measured) Cmt Ret @ 6645', cmt f/6645'-6650',cast iron BP @ 6650' true vertical 6923' feet Effective depth: true verticalmeasured 6645' feet 6349' feet Junk(measured) 0~/ G/~kL Casing Length Size Cemented Measured depth True vertical depth Structural 266' 30' Driven 266 266 Conductor 630' 20 1338 sx 630' 630' S u rface 3237' 13-3/8" 2700 sx 3237' 3155' Intermediate Production 7232' 9-5/8" 2100 sx 7232 6923 Liner Perforation depth: measured See Attached i? i:.-(,.., true vertical See Attached q Tubing (size, grade, and measured depth) LS: 3-1/2", 9.2#, L-80, TDS TBG @ 5848' TM SS: 3-1/2', 9.2#, L-80, TDS TBG @ 5815' TMAIg. ska 0il,~,~ 6~s C~ns. Packers and SSSV (type and measured depth) ~ ~, ?, ~,'. ~$. BAKER MOD "D" SUMP PKR @ 6620', BAKER SC-IL PKR @ 5891' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: Conversion to injector. 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: (,f~.~¢ f~l,;~-~-'~ 17.Signed:l hereby certify ~///~/,~and co rrect to the best of my knowledge.Title:-,4 -- I t///~ [ ,~ ~/// Reservoir Engineer Date:~'r ~ ('~" ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity.__ BOP Test Location clearance I ,_~'- ~'~- Mechanical Integrity Test ~ Subsequent form required 10- I,~ c~ ~ . OO¢ ORIGINAL SIGNED-By ,~obert N. Chdstenson Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE A-6: BCD: D: MEASURED DEPTH DEPTH 6160-6230 6518-6568 6581-6607 6645-6647 6663-6683 6700-6727 6788-6800 BAKER WELL #17 ADL 17595 PERFORATION RECORD TRUE VERTICAL DEPTH STATUS 5746-5775 SQUEF-~ED 5813-5863 OPEN 5879-5947 OPEN 6097--6149 OPEN 61 64-6211 OPEN 6226-6275 OPEN 6287-6313 OPEN 6351-6353 OPEN 6367-6386 DST 6403-6429 DST 6489-6500 DST RE IVED Aladm Oil & Gas C(ms. Com~ Anchorage RECEIVED JAN - 9 t992 Alaska 0u & u~s tons. (Jomm~ss,~ Anchorage 13~3/8' 68# @ 3237~ BAKER SC-1 PKR @ 5537, BAKER WELD SCREEN GRAVEL PACK 20-40 MESH OTTAWA SAND BAKER SC-1 PKR @ 5947, ISOLATION DISC 5955' BAKER WELD SCREEN GRAVEL PACK 20-40 MESH O3-1'AWA SAND BAKER SUMP PKR @ 6s20' CMT RET @ 6645' CAST IRON BP @ 6650' 9-5/8" 47 & 53.5# @ 723Z 3 IKOBE BHA TUBING DETAIL LONG STRING 1.3-1/2' 8RD x 3-1/2' TDS XO 37' ?_ 3-1/2' 9.2# N-80 TDS TUBING 3. 3-1/2' TDS x 3-1/2' 8RD XO 5438' 4. KOBE 3' TYPE 'D' BHA 5439' 5. OTIS XA St F;VE AT 5678' 6. BAKER LOCATOR SUB WI SEALS 5537' 7. OTIS XA S/Fm~E AT 5678' 8. OTIS XA S/FFVE AT 5898' g. OTIS ~(' PROFILE 2_313' 5930' 10. BAKER SEALS 5943' SHORT STRING A. 3-1/2' TDS x 3-1/2- 8RD XO 37, B. 3-1/2' 9.2# N-80 TDS TUBING C. 3-1/2' TDS x 2-7/8' 8-RD XO A-3: 5761' - 5782' A-4: 5807' - 5934' FRAC'D W/39,000 # SQZ'D 'A-6' SAND PERFORATIONS 6Q22'- 6052' 'BCD' ZONE INTERVA~ 6002'- 6143' 6160'- 6230' 6454'- 65O2' 6518'- 6568' 6~8~ '- 6607' ~.";'/ ~,',~ 'i9~)~ ~ SQZ PERFS F/6645.5'- 6647.5' SQZD wrrH 200 sxs CMT 'D' ZONE INTERVALS 6663'- 6683' 6788'- 6800' ADL 17595 WELL NO. 17 COMPLETION SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: GRB SCAL~ NONE DATE: 4~-g2 Unocal Corporation Agricultural Products 909 West 9® Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL October 26, 1999 Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Reactivation and Expansion of the Baker Waterflood Dear Blair: Due to the short economic life of oil operations in Cook Inlet and the cost to repair the waterflood facilities on the Baker platform, Unocal recently took a close look at the possibility of permanently terminating the waterflood operations on the Baker platform. After a review of the success at the Cross-Timber's A platform and realizing we could obtain variances on several wells, Unocal has decided to go forward with the reactivation and expansion of the Baker Platform waterflood. It has been down due to a series of mechanical difficulties since September 1996. The plan is to repair all the surface facilities and _~'hvert five shut-in vroduce~-t~ iniecti__~9~ No downhole modifications are planned except closing sliding sleeves and possibly perforating to improve injectivity. Three of these wells have packers and should pass conventional MIT's. The other two wells will require variances since there are no packers in the wells and the economics will not allow us to work the wells over. The variances will be based on a pair of temperature surveys before and after injection. There are no fresh water aquifers at risk and the gas reservoirs in this area of the field are either depleted or not at risk due to their location. Even if there were gas reserves in the immediate area, they would be protected through close monitoring of our injection operations which will recognize any casing/well failures. Below is a list of the conversions: B-7, B-16 and B-17 B- 15RD and B-27 should pass conventional MITs. will require variances. This program has been initiated and we should be ready for injection around the end of November. This is a final effort in the life of the reservoir's main fault block to maximize the recovery of the Tyonek and Hemlock intervals which are currently near the end of their waterflood life. We expect to see response within 12 months and will probably terminate the waterflood operations permanently if no response is recognized. The facilities modifications are nearing completion and pre-injection temperature surveys are being scheduled for all the wells. Once waterflood is active in our current injectors we will run the MIT's on the first three wells, begin injection into the 5 new wells and after 30 days of injection we will rerun the temperature surveys on B-15RD and B-27 to prove casing integrity. Attachments: 10-403 Forms Wellbore Diagrams Structure/Location Map Reactivation Plans Detailed Plan for each well Senior Reservoir Engineer Cook Inlet Waterflood Management Overall Plan for waterflood reactivation on the Baker Platform 1) Repair surface piping, chemical systems, filter systems and pumps. 2) Install new control and metering systems 3) Start up waterflood in B-4, B-12L, and B-23 which are currently approved for injection. 4) Run conventional MIT's on B-7, B-16 and B-17. 5) Run temperature surveys on B-7, B-16, B-17, B-15RD and B-27. 6) Begin injection in all new wells (temporary permission to inject required on B-15RD and B-27). 7) After 30 days, rerun temperature surveys on B-15RD and B-27. 8) Obtain Variance on B-15RD and B-27 based on temperature survey results. 9) Monthly Reporting of daily monitoring on B-12, B-15RD and B-27 with reports sent to AOGCC. 10)Circulate inhibited fluid after waterflood response is recognized. 11)Shut-in operations if no response is seen after 12 months. 12)Renew Variances on B-12, B-15RD and B-27 every other year. B-7 Plan 1) Hookup permanent or temporary injection equipment. 2) Circulate out all power-oil with waterflood water, close both sliding sleeves, gauge tbg and tag bottom. 3) Run conventional MIT and obtain final approval to inject. 4) Hookup permanent injection metering and controls. 5) Inject into the Tyonek A-Zone to support B-6 production B-16 Plan 1) Hookup permanent or temporary injection equipment. 2) Circulate waterflood water, close sliding sleeve, gauge tbg and tag bottom. 3) Run conventional MIT. 4) Obtain approval of MIT. 5) Hookup permanent injection metering and controls. 6) Inject into the Tyonek F-Zone to support B- 11 and B- 13 production. 7) If extra platform capacity exists after the full expansion is completed: Add tbg punch to allow injection into the BCD zone. Add perforations into the Tyonek A-Zone. B-17 Plan 1) Hookup permanent or temporary injection equipment. 2) Circulate out all power-oil with waterflood water and close sliding sleeve #5. 3) Tag isolation disk at 5955 MD and make sure sliding sleeves #7 & 8 are open 4) Run conventional MIT and obtain final approval to inject. 5) Hookup permanent injection metering and controls. 6) Inject into the Tyonek A-Zone to support B-5 and B-6 production B-15RD Plan l) Run pre-injection temperature survey for baseline data, gauge tbg, and tag cement plug. 2) Hookup permanent or temporary injection equipment. 3) Circulate out all power-oil with waterflood water. 4) Verify temporary permission to inject has been granted. 5) Inject for 30 days into the Tyonek A-F zones. 6) Shut-in for 12 hours and re-run temperature survey. 7) Analyze temperature surveys to prove casing integrity. 8) Obtain variance based on temperature surveys. 9) Hookup permanent injection metering and controls. 10) Inject into the Tyonek A-F zones to support B-6 and B-11 production IVED Ala Oil & C es Geas. ComPri B-27 Plan 1) Run pre-injection temperature survey for baseline data, gauge tbg and tag drillable bridge-plug. 2) Hookup permanent or temporary injection equipment. 3) Circulate out all power-oil with waterflood water. 4) Verify temporary permission to inject has been granted. 5) Inject for 30 days into the Tyonek A-D zones. 6) Shut-in for 12 hours and re-run temperature survey. 7) Analyze temperature surveys to prove casing integrity. 8) Obtain variance based on temperature surveys. 9) Hookup permanent injection metering and controls. 10) Inject into the Tyonek A-D zones to support B-5 and B-28 production -'-'7 REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging __ Perforate X -- Repair well Pull tubing Other 2. Name of Operator 15. Type of Well: Development X Union Oil Company of Caifornia (Unocal) Exploratory 3. Address Strafigraphic __ P.O. Box 196247 Anchorage, AK 99519-624 s~r~ce 4. Location of well at surface 1982' FNL, 481' FWL, Sec. 31, T9N, R12W, SM At top of productive interval 6022' MD 529' FNL, 814' FWL, Sec. 31, T9N, R12W, S.M. At effective depth 6645' MD 420' FNL, 927' FWL, Sec. 31, T9N, R12W, S.M. 6. Datum elevation (DF or KB) 101' RKB above MLW 7. Unit or Property name MGS State 17595 RECEIVED At total depth 7232' MD APR ~ 2 ,~-" 335' FNL, 1019' FWL, Sec. 31, T9N, R12W, S.IVIAlaska 0[! & 6as cons. C0mm 12. Present well condition summary Total depth: Effective depth: feet 8. Well number Well No. 17 9. Per~pproval number 92 =-005/~,..,,,;~.,~: 10. APl number 50-133-20381 11. Field/Pool ~sMMdle Ground Shoal ,Anch0ra_qe measured 7232' feet Plugs [measured)' Cement retainer 6645' true vertical 6923' feet Cement6645'- 6650' Cast Iron B.P. 6650' measured 6645' feet Junk (measured) true vertical 6349' feet Casing Length Size Cemented Measured depth True vertical depth Structural 266' 30" Driven 266' 266' Conductor Surface 630' 20" 1388 sxs 630' 630' Intermediate 3237' 13 3/8" 2700 sxs 3237' 3155' Production 7232' 9 5/8" 2100 sxs 7232' 6923' Liner Perforation depth: measured See attached true vertical Tubing (size, grade, and measured depth)LS: 3-1/2", 9.2#, L-80, TDS tubing @ 5848'_ TM SS: 3-1/2", 9.2#, L-80, TDS tubing @ 5815' TM Packers and SSSV (type and measured depth) Baker Model D Sump Backer at 6620' Baker SC-1L packer @ 5537', 5947', 6620' 13. Stimulation or cement squeeze summary A-4 zone fracture stimulated w/39,000# 20-40 carbolite Intervals treated (measured) 5807'--5934' Treatment description including volumes used and final pressure 3030 psi 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 81 69 255 0 0 15. Attachments Copies of Logs and ,Surveys runX __ Daily Report of Well Operations X_ 16. Status of well classification as: Oil X Gas __ Suspended _ _ Service 17. I hereby certify that the-foregoing is true and correct to the best of my knowledge. g~n'e~' Gary S. Bus~°'~~' ~) '-~'~ ~e Reqional Drilling Manager S~orm 10-404 Rev06/15/8~ ~ Date ~'- / ~--~'-') ~-- SUBMIT IN DUPLICATE 13~3/8' 68# @ 3237' BAKER SC-1 PKR @ 5537' BAKER WELD SCREEN GRAVEL PACK 20-40 MESH OTTAWA SAND BAKER SC-1 PKR @ 5947' ISOLATION DISC 5955' BAKER WELD SCREEN GRAVEL PACK 20-4O MESH OTTAWA SAND BAKER SUMP PKR @ 6620' CMT RET @ 6645' CAST IRON BP @ 6650' 9-5/8" 47 & 53.5# @ 7232' I 1 A 2 B 4 I KOBE BI-lA 5 TUBING DETAIL LONG STRING 1.3-1/2" 8RD x 3-1/2" TDS XO 37' 2. 3-1/2" 9.2# N-80 TDS TUBING 3. 3-1/2' TDS x 3-1/2" 8RD XO 5438' 4. KOBE 3' TYPE 'D' BHA 5439' 5. OTIS XA SLEEVE AT 5678' 6. BAKER LOCATOR SUB W/SEALS 5537' 7. OTIS XA SLEEVE AT 5678' 8. OTIS XA SLEEVE AT 5898' 9. OTIS 'X' PROFILE 2.313" 5930' 10. BAKER SEALS 5943' SHORT STRING A. 3-1/2" TDS x 3-1/2" 8RD XO 37' B. 3-1/2" 9.2# N-80 TDS TUBING C. 3-1/2" TDS x 2-7/8" 8-RD XO A-2: 5660' - 5704' A-3: 5761' - 5782' A-4: 5807' - 5934' FRAC'D W/39,000 # SQZ'D 'A-6" SAND PERFORATIONS 6022'- 6052' 'BCD' ZONE INTERVALS 6092'- 6143' 6160'- 6230' 6385'- 6438' 6454'- 6502' 6518'- 6568' 6581'- 6607' SQZ PERFS F/6645.5'- 6647.5' SQZD WITH 200 SXS CMT "D" ZONE INTERVALS 6663'- 6683' 6700'- 6727' 6788'- 6800' RECEiV APR 2 2 19~ Alaska Oil & Gas Cons. Anchorage ADL 17595 WELL NO. 17 COMPLETION SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: GRB SCALE: NONE DATE: 4-6-92 DATE BAKER 517 WORKOVER JOB HISTORY ETD COMMENTS 02/06/92 6645' 02/07/92 6645' 02/08/92 6645' 02/09/92 6645' 02/10/92 6645' 02/11/92 5947' APR 2 2 1992 Oii & 6as Oons. 6ommissio~-' Anchorage COMMENCED OPERATIONS AT 1200 HRS. SKIDDED RIG OVER WELL. RIGGED UP SERVICE LINES. DISPLACED WELL WITH 3% KC1 63 PCF. INSTALLED BPV'S AND REMOVED TREE. INSTALLED BOPE. TESTED BOPE TO 300/5000 PSI. PULLED BPV FROM THE SHORT STRING AND INSTALLED LANDING JOINT. CIRCULATED HOLE WITH 63 PCF BRINE. CHECKED HOLE FOR FLOW, OK. RIGGED UP WIRELINE AND CUT THE SHORT STRING AT 5813'. POOH WITH THE SHORT STRING AND STOOD BACK. POOH WITH THE LONG STRING AND STOOD BACK. LAYED DOWN THE KOBE BHA AND TAIL PIPE. SET TEST PLUG. TESTED BLIND RAMS TO 300/5000 PSI. PICKED UP 3-1/2" DRILL PIPE AND STOOD BACK. RIH WITH TSA MECHANICAL CUTTER AND BAKER RETRIEVING TOOL. CONT'D RIH. LOCATED ON THE SC-1 PKR AT 5895'. LOCATED ON THE XO SUB AT 5929'. RIH AND CUT THE 5.5" 175 BLANK PIPE AT 5958'. CONT'D IN HOLE AND ATTEMPTED TO RELEASE PACKER, NEG. POOH. RIH AND RECOVERED SC-1 PKR. CIRCULATE. POOH. RIH WITH TSA BEVELING TOOL AND 9-5/8" CSG SCRAPER. CONT'D RIH DRESSED OFF 5 5" 175 BLANK PIPE AT 5958'. CIRC· POOH· RIH WITH HIGH PRESSURE PACK OFF, CERAMIC DISK AND SC-iLR PACKER· WORKED OVER 5·5" STUB AT 5958'· DROPPED BALL AND PRESSURED UP ON D.P. TO SET THE PACKER· RELEASED SETTING TOOL· DISPLACED WELL FROM 63 PCF TO 78 PCF NaCl/NaBr BRINE· POOH AND LAID DOWN PKR TOOLS. RIH WITH 7" TCP GUNS. CONT'D RIH WITH 7" TCP GUNS. SET PKR PLUG IN SC-iL PACKER AT 5947'. PERFORATED THE A-4 SAND 5807' - 5934' WITH 7" 61 GM TCP GUNS AT 8 SPF. MONITORED WELL, OK. RELEASED PACKER AND REVERSE CIRCULATED THROUGH THE GAS BUSTER TO THE SHAKER PIT. POOH. 650' FROM SURFACE THE HOLE WAS NOT TAKING THE PROPER AMOUNT OF FLUID. RIH TO 5930 AND CIRC. WELL STABLE. POOH. DATE BAKER #17 WORKOVER JOB HISTORY ETD COMMENTS 02/12/92 5947' 02/13/92 5947' 02/14/92 5947' 02/15/92 5947' 02/16/92 5947' ~aT~ Oil & Gas Cons. Com~%s~%o~ CONTINUED POOH. ALL GUNS FIRED. RIH WITH A RETRIEVAMATIC PACKER TO 5936', NO FILL. SET PACKER AT 5468', TAIL AT 5757'. PRESSURE TESTED THE ANNULUS TO 1500 PSI. RIGGED UP DOWELL AND PRIMED THE TURBINES. PRESSURE TESTED THE SURFACE EQUIPMENT TO 10,000 PSI. PERFORMED A FRAC ON THE A-4 PERFORATIONS. 160 BBL GEL PRE-PAD, 39,000# 20/40 MESH CARBOLITE AND CARBOPROP MIX, AT A MAX RATE OF 15 BPM. MAX PRESSURE 3030 PSI. ALLOWED WELL TO SIT FOR 3 HRS. FLOWED BACK 190 BBLS OF 8.4 PPG FRAC FLUID. REVERSED OUT 1-1/2 D.P. VOLUMES. MW 78 PCF IN AND OUT. TAGGED FILL AT 5768'. ATTEMPTED TO REVERSE CIRCULATE FILL, NEG. POOH. RIH WITH A MULE SHOE AND REVERSED OUT FRAC SAND FROM 5768'-5932'. RIH WITH BAKER 7" OD TCP GUNS. HOLE TAKING 40 BBLS OF FLUID PER DAY. CONTINUED TO RIH WITH 7" GUNS. CORRELATED GUNS WITH GR/CCL. POSITIONED GUNS. SET THE PACKER AT 5626' WLM. FIRED THE GUNS. PERFORATED THE A-2 FROM 5709' -5660' (49'), AND THE A-3 FROM 5782' -5761' (21') USING 61 GM CHARGES, AT 8SPF. OPENED THE PACKER BYPASS, WELL TAKING FLUID. FLUID LEVELS AT 950' ANN, AND 510' IN D.P. SPOTTED A 30 BBL XANVIS PILL, NO RETURNS. SPOTTED A 35 BBL XANVIS PILL NO RETURNS TO SURFACE. CONT'D TO BUILD 250 BBLS 76 PCF NaCl/NaBr/3% KCl BRINE. SHOT F.L. AT 745'. LOAD D.P. WITH 40 BBL THIXSAL PILL SET 9-5/8" PACKER 5623'. PUMPED AND ADDITIONAL 57 BBLS THIXSAL AND DISPLACED WITH 34 BBLS BRINE, MAXIMUM PRESSURE 120 PSI. LOADED DRILL PIPE WITH 36 BBLS XANVIS, SET PKR AT 5620', FOLLOWED XANVIS WITH 106 BBLS THIXSAL AT 2400 HRS. DISPLACED SIZED SALT PILL WITH 50 BBLS 76 PCF BRINE, MAXIMUM PRESSURE OF 300 PSI. SHOT FLUID LEVEL IN ANNULUS AT 525'. CONTINUED TO BUILD MUD VOLUME. FILLED ANNULUS WITH 29 BBLS 76 PCF BRINE. HOLE STARTED TAKING FLUID AT 15- 20 BPH. UNLOADED WORK BOAT AND BUILT DATE BAKER #17 WORKOVER JOB HISTORY ETD COMMENTS 02/17/92 5947' MUD VOLUME. BUILT 10.1 PPG NaCl/NaBr/THIXSAL BRINE. WITH THE 9-5/8" PKR SET AT 5625' PUMPED 142 BBLS THIXSAL LCM PILL. MAXIMUM PRESSURE 350 PSI. OPENED PACKER BYPASS AND REVERSED OUT 52 BBLS BRINE. POOH WITH PACKER AND GUNS. ALL SHOTS FIRED. RIH WITH BAKER PLUG CATCHER AND A 9-5/8" CASING SCRAPER. FLUID LOSS TO DATE, 1041 BBLS. 02/18/92 5947' 02/19/92 5947' 02/20/92 5720' RECEIVED · !a~9 Alaska 0il & Gas Cons, uo~,~s=,~'- ~nchorage 02/21/92 5810' CONT'D TO RIH WITH 9-5/8" SCRAPER TO 5043' CIRC. RIH AND TAGGED SAND AT 5927'. WASHED DOWN FROM 5927' TO 5947' AND REVERSED OUT. LOST RETURNS WITH NO SAND TO SURFACE. PULLED TO 5506' (A-4 PERFS WERE RATTY) RAN A TEMP LOG SHOWING THE THIEF ZONE FROM 5660'-5692'. PUMPED A 45 BBL THIXSAL LCM PILL AND SQUEEZED, MAXIMUM PRESSURE 110 PSI. BEGAN MIXING 115 BBLS THIXSAL PILL. FLUID LOSS TO DATE 1416 BBLS. CONT'D MIXING 130 BBL THIXSAL PILL. PUMPED 130 BBL THIXSAL PILL, MAXIMUM PRESSURE 350 PSI. POOH WITH SCRAPER AN PLUG CATCHER. RIH WITH 185' OF DRILL PIPE AND A RETRIEVABLE PACKER. MIXED AND PUMPED 34 BBLS CLEAR BRINE DOWN THE D.P. DUMPED 55 SXS OF 20-40 SAND DOWN THE DRILL PIPE LETTING THE SAND SETTLE OUT. TAGGED THE SAND AT 5697'. REVERSED OUT FROM 5697' TO 5720'. RECOVERED 4 CU FT OF SAND AND 7 CU FT OF SALT. SET RETRIEVABLE PACKER AT 4790'. TESTED THE ANNULUS TO 1000 PSI, OK. TESTED THE SURFACE EQUIP TO 300 PSI , OK. MIXED AND PUMPED 500 SXS OF 16.4 PPG CLASS "G" CEMENT WITH 0.6% CD-31, 0.5% A-7, AND 1 GAL/100 SXS FP-61, WITH 1/4 LB/SACK CELLO FLAKE. INITIAL SQUEEZE PRESSURE 250 PSI @ 4 BBL/MIN UP TO 150 PSI AT 1 BBL/MIN AND THE FINAL PRESSURE WAS 2750 PSI AT 1/4 BBL/MIN. PLACED 463 SXS BEHIND PIPE. CEMENT IN PLACE AT 2000 HRS. POOH. RIH WITH AN 8-1/2" BIT. DRILLED CEMENT STRINGERS FROM 5355' - 5398'. DRILLED SOFT CEMENT FROM 5448-70'. DATE BAKER #17 WORKOVER JOB HISTORY ETD COMMENTS 02/22/92 5947' DRILLED HARD CEMENT FROM 5470' -5711' FELL OUT OF CEMENT AT 5711' AND TAGGED THE SAND TOP AT 5720'. CIRC. WASH AND REVERSE CIRC FROM 5720' -5810'. WASH AND REVERSE SAND FROM 5810-5936'. POOH. RIH WITH BAKER PACKER PLUCKER AND 9-5/8" CASING SCRAPER. WASHED AND REVERSED FRAC SAND AND CEMENT CHIPS FROM 5928-47'. WORKED OVER THE PACKER PLUG AND RECOVERED PLUG. POOH. RIH WITH A 2- 7/8" OD 7" LONG SNORKEL TUBE AND REVERSE CIRCULATED THE SAND FROM ON TOP OF THE DEBRIS DISK AT 5949-56'. CLEANED SHAKER PITS AND BUILT NEW BRINE. 02/23/92 5947' 02/24/92 5537' RECEIVED APR 2 aa¢ Alaska Oil & Gas Cons. Commiss%o'a Anchorage 02/25/92 5537' 02/26/92 5537' 02/27/92 5537' CONT'D BUILDING NEW MUD VOLUME. NaCl/NaBr/3% KCl TO 10.1 PPG. FILTERED THE BRINE AND REVERSE CIRCULATED. POOH. CONT'D POOH WITH THE SNORKEL ASSEMBLY. RIH WITH THE GRAVEL PACK ASSEMBLY AND STABBED INTO THE SCL-iR PACKER AT 5947'. SET THE UPPER PACKER AT 5537' AND TESTED SAME. RIGGED UP BAKER SAND CONTROL AND PUMPED' 100 GAL SODIUM HYPOCHLORITE IN 20 BBLS OF FILTERED BRINE. ESTABLISHED INJECTION RATE AT 3-1/2 BBL/MIN @ 1000 PSI. MIX AND PUMP 55 CF 20/40 SAND SLURRIED IN 31 BBLS OF FILTERED WATER. FINAL INJECTION RATE 1000 PSI @ 3-1/2 BBL/MIN. ACHIEVED PACK OFF AT 1300 PSI. PICKED UP AND REVERSE CIRCULATED THREE TUBING VOLUMES, NO SAND RETURNS. POOH. CONT'D POOH AND LAYING DOWN DRILL PIPE. RIH WITH THE COMPLETION, DUAL 3-1/2" TUBING. HYDROTESTED EACH STAND TO 3500 PSI. WORKED BAKER SEAL ASSEMBLY THROUGH THE PACKER AT 5942'. FINISHED RIH WITH DUAL 3-1/2" PRODUCTION STRINGS. LANDED THE COMPLETION AND INSTALLED THE BPV'S. REMOVED BOPE. INSTALLED TREE AND TESTED TO 5000 PSI. RIGGED UP OTIS AND OPENED THE SLIDING SLEEVES AT 5678' AND 5895'. PUMPED A KOBE 3"x 2-1/8"x 2-1/8" BDB PUMP. CLEARED THE DECKS AND PREPARED TO MOVE. RELEASED THE RIG AT 2400 HRS. STATE OF ALASKA ~" ',} ~,? .~ ~! ALA. , OIL AND GAS CONSERVATION COME,. ,ON '~ i~- ~ ~" }..T~ ~. ...~ APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend Alter casing__ Repair well X Change appro/ed program 2. Name of Operator UNION OIL COMPANY FOR CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247, ANCHORAGE AK 99519-6247 4. Location of well at surface 1982' FNL, 481' FWL SEC 31, T9N, R12W, SM At top of productive interval 6022' MD (5746' TVD) 529' FNL &814' FWL, SEC 31, T9N, R12W, SM At effective depth 6645' MD (6349' TVD) 42O' FNL &927' FWL, SEC 31, T9N, R12W, SM At tolal depth 7232' MD (6923' TVD) 335' FNL, 1019' FWL, SEC 31, T9N, R12W, SM Operations shutdown __ Re-enter suspended well__ Plugging __ Time extension __ Stimulate __ Pulltubing Variance __ Perforate X Other__ 5. Type of Well: Development Exploratory Stratig raphic 6. Datum elevation (DF or KB) 101' RKB ABOVE MLW 7. Unit or Property name MGS STATE 17595 8. Well number WELL NO. 17 9. Permit number 10. APl number 50-133 -2O381 11. Field/Pool MIDDLE GROUND SHOAL feet 12. Present well condition summary Total depth: measured 7232' true vertical 6923' feet feet Effective depth: measured 6645' feet true vertical 6349' feet Plugs (measured) CEMENT RETAINER 6645' CEMENT 6645' - 6650' CAST IRON B.P. 6660' Junk (measured) Casing Length Size Cemented Measured depth Structural 266' 30" DRIVEN 266' Conductor 630' 20" 1338 SXS 630' Surface 3237' 13-3/8" 2700 SXS 3237' Intermediate Production 7232' 9-5/8" 2100 SXS 7232' Liner Perforation depth: measured true vertical SEE ATTACHED Tubing (size, grade, and measured depl~) L.S: 3-1/2", 9.2#, L-80, TDS TUBING @ 6848' TM S.S: 3-1/2", 9.2#, L-80, TDSTUBING @ 5815' TM Packers and SSSV (type and measured depth) BAKER MODEL D SUMP PACKER AT 6620' BAKER SC-1L PACKER AT 5891' 13. Attachments Description summary of proposal __ Detailed operations program X True vertical depth 266' 630' 3155' 6923' RECEIVED ,JAN - 9 t99 Maska Oil & Gas Cons. Com~ Anchorage BOP sketch X 14. Estimated date for commencing operation FEBRUARY 5, 1992 16. If proposal was verbally approved Name of approver I 5. Status of well classification as: Oil X__ Gas __ Date approved Service Suspended__ 17. I hereby certify that t/he, foregoing is true and correct to the best of my knowledge. Signed GARY S. BUS{H-~(3.-,..,-~ ~...~. ,.,,J~, Title REGIONAL DRILLING MANAGER .("'\ ('~ FOR COMMISSION USE ONLY Conditions of approval: Nbtity Co~mission so representative may witness Plug Integrity __ BOP Test Location clearance Mechanical Integrity Test__ S--~bsequentform required 1--~- /-~D ~ Approved by the order of the Commission Date t Z-z~-~ \ Approval No. /-3o- q_? .... Commissioner Date /'/~ - c),~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE A-6: BCD: D' MEASURED DEPTH DEPTH 6022-6052 6092-6143 6160-6230 6385-6438 6454-6502 6518-6568 6581-6607 6645-6647 6663-6683 6700-6727 6788-6800 BAKER WELL #17 ADL 17595 PERFORATION RECORD TRUE VERTICAL DEPTH STATUS 5746-5775 SQUEEZED 5813-5863 OPEN 5879-5947 OPEN 6097-6149 OPEN 61 64-6211 OPEN 6226-6275 OPEN 6287-6313 OPEN 6351-6353 OPEN 6367-6386 DST 6403-6429 DST 6489-6500 DST RECEIVED JAN - 9 t99~ Alaska 0it & Gas Cons. Anchorage BAKER WELL # 17 PROCEDURE MIDDLE GROUND SHOAL 1. MOVE RIG OVER ~MGS 17595 #17, LEG#4, SLOT#7 2. KILL THE WELL WITH 3% KCl COMPLETION FLUID 3. INSTALL BPV' S, REMOVE TREE. 4. INSTALL AND TEST THE BOPE TO 5000 PSI 5. PULL AND STAND BACK THE DUAL HYDRAULIC PRODUCTION SYSTEM 6. RUN A 9-5/8" SCRAPER TO THE SC-1 PACKER AT 5891'. 7. SET AN SC-1 PACKER PLUG IN THE PACKER AT 5891' WITH DRILL PIPE AND SPOT SAND. 8. PRESSURE TEST 9-5/8" CASING AT INTERVALS. 9. CHANGE OVER TO CLEAN COMPLETION FLUID. 10. RUN A CARBON OXYGEN LOG ACROSS THE "A" ZONE. 11. PERFORATE THE LOWER "A" ZONE WITH TCP GUNS. 12. FRACTURE THE LOWER "A" ZONE INTERVAL. 13. RECOVER THE PACKER PLUG. 14. RUN A 5.5" OD GRAVEL PACK LINER ASSEMBLY. 15. GRAVEL PACK FROM 5460' - 5891'. 1'6. PLACE A WIRELINE RETRIEVABLE PLUG IN THE 'X' NIPPLE IN THE BOTTOM OF THE SNAP LATCH ASSEMBLY. 16. RUN A DUAL KOBE PRODUCTION STRING WITH THE CAVITY AT 5300 17. REMOVE THE BOPE AND INSTALL THE TREE. 18. RETURN THE WELL TO PRODUCTION. RECEIVED JAN - 9 t992 Alaska Oil & Gas Oons. comm'~ss%On Anchorage 13-3/8" 68# @ 3237' BAKER SC-1 PKR @ 5891' BAKER WELD SCF GRAVEL PACK 20-40 MESH OTTAWA SAND BAKER SUMP PKR @ 6620' CMT RET @ 6645' CAST IRON BP @ 6650' 9-5/8" 47 & 53.5# @ 7232' CURRENT 1 I ^ I 3 c 1) 2) D 31 4 C 3 E 5 ~ 6: ~9KOBEBHA J ~ 8', ..... TUBING DETAIL LONG STRING (POWER FLUID) CIW TUBING HANGER (BUn') @ 31.00' 3-1/2 BLrl-r PIN x 3-1/2" TDS PIN @ 31.80' 3-1/2" 9.2# N-80 TDS W/SP CL CPLGS 3-1/2" 9,2# N-80 TDS PUP @ 5706.37' 3-1/2 TDS BOX x 3-1/2 EU 8RD PIN @ 5813.66' 3-1/2 EU 8RD BOX x 3-1/2 TDS PIN @ 5836.60' 3-1/2" 9.2# N-80 TDS PUP @ 5837.83' 3-1/2" TDS BOX RE-ENTRY GUIDE @ 5847.63' KOBE 3" MODEL "B" BHA @ 5813.95' SHORT STRING (PRODUCTION) CIW TUBING HANGER (BU'i-r) @ 31.00' 3-1/2 BUTT PIN x 3-1/2" TDS PIN @ 31.80' 3-1/2" 9.2# N-80 TDS W/SP CL CPLGS 3-1/2" 9,2# N-80 TDS PUP @ 5707.03' 3-1/2 TDS BOX x 2-3/8 EU 8RD PIN @ 5803.95' 2-3/8 EU 8RD PUP @ 5805.26' SQZ'D "a-6" SAND PERFORATIONS 6022'-6052' "BCD" ZONE INTERVALS 6092'- 6143' 6160'- 6230' 6385'-6438' 6454'-6502' 6518'-6568' 6581'-6607' ECEIVEO JAN - 9 t997- SQZ PERFS F/6645.5'- 6647.5' SQZD WITH 200 SXS CMT "D' ZONE INTERVAL~R 6663'-6683' 6700'-6727' 6788'-6800' Alaska 0il & Gas Cons. (;om[ Anchorage ADL 17595 WELL NO. 17 COMPLETION SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 4-01-91 13-3/8" 68# @ 3237' BAKER SC-1 PKR @ 5460' BAKER WELD SCRE GRAVEL PACK 20-40 MESH O'l-rawa SAND BAKER SC-1 PKR @ 5891' BAKER WELD SCR~ GRAVEL PACK 20-40 MESH OTTAWA SAND BAKER SUMP PKR @ 6620' CMT RET @ 6645' CAST IRON BP @ 6650' 9-5/8" 47 & 53.5# @ 7232' I I I KOBE BHA , , PROPOSED TUBING DETAIL DUAL 3-1/2" x 3-1/2" HYDRAUUC COMPLETION SQZ'D 'a-6" SAND PERFORATIONS 6022'- 6052' "BCD' ZONE INTERVALS 6092'- 6143' 6160'- 6230' 6385'- 6438' 6454'- 6502' 6518'- 6568' 6581 '- 6607' SQZ PERFS F/6645.5'- 6647.5' SQZD WITH 200 SXS CMT R E¢ E IV 6663'- 6683' 6700'- 6727' JAN - 9 6788'- 6800' Alaska 0il & Sas Cons, Con Anchorage ADL 17595 WELL NO. 17 COMPLETION SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: GRB SCALE: NONE DATE: 12-19-91 PLATFORM BAKER .DRILLING STACK III PITCHER NIPPLE- 16' ID W/10" FLOWLINE ANNULAR BOP "NL SHAFFER' 13 5/8' 5000 PSI BX-160 ASSY WT. 13,650 LBS. DBL GATE BOP 'NL SHAFFER' 13 5/8' 5000 PSi BX-160 ASSY WT. 16,500 LBS. MUD CROSS- 13 5/8' BORE WI4' 5000 PSI VALVES SGL,-GATE BOP 'NL SHAFFER' 13 5/8' 5000 PSI BX-160 ASSY WT. 9100 LBS. RISER 18'OD 13 5/8' 5000 FLG RECEIVED JAN - 9 t992 'a, laska OJi & Gas Cons. Commission Anchorage LOWER RI8ER 11' ID W/10' 5000 PS1 FLG (RX-54) · . . --" STATE OF ALASKA -'-'-. ALASKA OIL AND GAS CONSERVATION COMMIS,.,,ON APPLICATION FOR SUNDRY APPROVALS Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate x__. Perforate __ Other __ 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well ~ Change approved program ~ Pull tubing ~ Variance __ 2. Name of Oper~NO''3AL ) 5. Type of Well: Jnion Oil Company of California Development_X__~ Exploratory __ 3. Address Stratigraphic __ ?. O. BOX 196247, Anch. , AK, 99519 Service __ 4. Location of well atsurface Leg #4, Conductor #7 982· FNL & 481· FWL, Sec 31, T9N, R12W, SM Attopofproductiveinterva~022' MD (5746' TVD) 529' FNL & 814' FWL, Sec 31, T9N, R12W, SM At effective depth 6650 ' MD ( 6354 ' TVD ) 420· FNL & 927· FWL, Sec 31, T9N, R12W, SM At total depth 7232 ' MD ( 6923 ' TVD ) 335· FNL & 1019· FWL, Sec 31, T9N, R12W, SM 12. Present well condition summary Total depth: measured 7,232 ' feet true vertical 6,923 ' feet Plugs (measured) Effective depth: measured 6,645 ' feet Junk (measured) true vertical 6,349 ' feet Casing Length Size Cemented Structural 266 ' 30" DRIVEN Conductor 630 · 20" 1338 SXS Surface 3237' 13-3/8" 2700 SXS Intermediate Production 7232' 9-5/8" 2100 SXS Liner Perforation depth: measured See attached true vertical LS: Tubing (size. grade, and measured depth;~S: 61[~u¢ ~° r~J::C~ ~B)~T,w feet 7~ or~le~r~ na~n'~a595 8. Well number Well No. 17 9. Permit number 85-217 10. APl number 50-- Q33-20381 11. Field/Pool Middle Ground Shoal N 0V 2 2 1991 Alaska,.Oil .& Gas Cons. Comm'tssioo Nlchorage. Measured depth True vertical depth 266' 266' 630' 630' 3237' 3155· 7232' 6923' 3-1/2", 9.2#, L-80, TDS Tubing @ 5848' TM 3-1/2", 9.2#, L-80, TDS Tubing @ 5815' TM Baker Model D sump pkr @ 6620', Baker SC-iL pkr @ 5891' Packers and SSSV (type and measured depth) Description summary of proposal __ Detailed operations program ~ BOP sketch 13. Attachments Gas __ Suspended __ 14. Estimated date for commencing oPeration 115. Status of well classification as: December 5, 1991 16. If proposal was verbally approved Oil x__ Name of approver Date approved Service 17. I hereby certify th~t4~e foregoing is true and correct to the best of my knowledge. t. Signed Gary-F~. ~ush Title Regional Drilling Mana~)a~ k, ) FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ z~,~,..) 4- Mechanical Integrity Test__ Subsequent form required 10- . ORIGINAL SIGNED LONNtE C, ,. Commissioner Date 11- ~ - ~-~ t Approved by order of the Commissioner FOrm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ¢' ZONE B-1 B-2 B-3 C-1 C-2 C-3 C-4 D-1 G-2 G-3 MGS 17595 #27 PERFORATION RECORD CONDITION MEASURED DEP. TH SQUEEZED OPEN OPEN OPEN OPEN OPEN OPEN OPEN ISOLATED BY CMT RET @ 9950' SQUEEZED ISOLATED BY CMT RET @ 9950' SQUEEZED ISOLATED BY CI~T-RET @ 9950' SQUEEZED ISOLATED BY CMT RET @ 9950' SQUEEZED 7476'-7578' 7668'-7765' 7788'-7875' 7938'-7993' 8072'-8163' 8180'-8262' 8274'-8328' 8476'-8511' 9968'-10,052' 10,758'-10,931' 10,932'-10,938' 10,939'-10,953' 10,954'-10,960' 10,961'-10,973' 10,974'-10,980' 10,981'-11,114' TRUE VERTICAL DEPTH 5845'-5847' 5914'-5984' 6000'-6062' 6106'-6145' 6200'-6266' 6277'-6335' 6343'-6381' 6487'-6513' 7707'-7781' 8431'-8598' 8599'-8605' 8606'-8619' 8620'-8626' 8627'-8639' 8640'-8646' 8647'-8778' RECEIVED NOV 1991 AJas~ Oil .& Gas Cons. CommissiOn /~mchorage I 13-3/8' 54.5, ~_J 61 & 68# @34O7' TOP OF LINER @ 8590' 9-5/8' 40, 43.5, 47 & 53.5# @ 7565' PBTD @ 11070' 7' 29 & 35# @ 11127' i I A TUBING DETAIL LONG STRING (POWER FLUID) 1) ClW HANGER (BUTT~OWN, EUE 8RDqJP) 2) 3-t/2 BUTT PIN(UP) x TDS PIN(DOWN) X~NER ~ 31.01~ r3) 3.1/2. 9.2~ N4tO TB~ TDS WI SP CL CPLGS 4) 3-1/2 TDS BOX x 3-1/2 EU 8RD PIN X431~ER ~ 7641' 53 KOBE 3' MODEL 'B' BI-IA ~ 764~ ;SHORT STRING (PRODUCTION) A) CIW H/~GER (BUTT-DOWN, EUE 8RD4JP) B) 3-1/2 BUTT PIN(UP) x TDS PIN(DOWN) X~VER ~ 31.0~ C) 3-1/2' 9.2# N~0 TB~ TDS WI SP CL CPLGS D) 3-1/2 TD$ BOXx 2~f8 EU 8RD PIN X43VER E) 2~11· 4.6~ N~0 EU 8FID PUP ~ 763~ TNL A;S;SEMBLY 6) 3-1/2' EU 8RD BOX x 3-1/2' BUTT X43VER ~766E 7) 3-1/2' g.2# N~o BUTT PUP (t0~ 8) 3-1/2' BUTTW1REUNE RE-ENTRY GUIDE ~ 7677' 'B' ZONE PERFORATIONS 7476'- 7578' SQZD 7668'- 7765' 7788'- 7875' 'C' ZONE PERFORATIONS 7938'-7993' 8072'-8163' 8180'-8262' 8274'-8328' 'D' ZONE PERFORATIONS 8476'- 8511' DRILLABLE BP @ 9950' 'G' ZONE PERFORATIONS R £ C £ IV 10932'-10938' 10954'-10960' 10974'-10980' ~as~ Oit.& 6as Cons. ADL 17595 WELL NO. 27 COMPLETION SCHEMATIC UNION OIL COMPANY OF CAUFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 2-13-91 n DF[~PO~M ~ ~OOn nat ACTD ROUREZE .... I 0 T{TT~ TTTF, eTA~qT~TG VAT,VE Ott er Tnt- T, TN~ TEXAS ®~ TOOLS OGT. 14 1-0518 TUBING STRIPPER/PACeR S,O00 psi Workin~ Pressure ~ H~S Service. L_,.[ ISoIMOOoo~ 10~4~. '_ 5~:~s 1.00'Series DS322 t.25"Serles DS323 ~!as~ Oil.& Gas Cons. Corotar ~ ' :/~ora~. ~ I.~ I TX-TOOLS HOU phone: (713) 6206 STATE OF ALASKA ALa'~(A OIL AND GAS CONSERVATION COM M I~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging Pull tubing -¢ Alter casing ~ Repair well __ 2. Name of Opera~NOCAL) I 5. TypeofWell: Un'on Oil Comoanv of California 3. Address ~ P.O. Box 190247, Anch., AK, 99519 4. Location of well at surface Leg #4, Conductor # Perforate _.~ Pull tubing ~ Other ..-z- Development Exploratory Stratigraphic Service 1982' FNL & 481' FWL, Sec 31, T9N, R12W, SM Attopofproductiveinterva~022' MD (5746' TVD) 529' FNL & 814' FWL, Sec 31, T9N, R12W, SM 6650' MD (6354' TVD) At effective depth 420' FNL & 927' FWL, Sec 31, T9N, R12W, SM 7232' MD (6923' TVD) 3~jt~alc~t~ & 1019' FWL, Sec 31, T9N, R12W, SM 6. Datum elevation (DF or KB) 101 ' RKB ABOVE MLWfeet 7. Unit or Property name MGS STATE 17595 8. Well number Well No. 17 9. Permit nurr~_~r/_aJ~l~r.~val number i0. APl numb,__e~ 3_2 0 3 8 1 50-- 11. Field/~ddle Ground Sho 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 266 ' Conductor 630 ' Surface $ 237 ' Intermediate Production 7232 ' Liner Peal@ration depth: measured 7,232 ' feet Plugs (measured) feet 6,923' feet Junk (measured) 6,645' feet 6,349' Size 0" 0" 3-3/8" 9-5/8" Cemented DRIVEN 1338 SXS 2700 SXS RECEIVEL) Measured de~tb,_ ~o ~O~%~cal depth 2 2 6 g ' 630' 630' 3237' 3155' 2100 SXS 7232' 6923' true vertical See Tubing (size, grade, and measured depth) attached LS: 3-1/2", 9.2#, L-80, TDS Tubing @ 5848' TM SS'. 3-1/2", 9.2#, L-80, TDS Tubing @ 5815' TM Packers and SSSV (type and measured depth) Baker Model D sump pkr @ 6620', Baker SC-iL pkr @ 5891' 13. Stimulation or cement squeeze summary Intervals treated (measured) See attached Treatment description including volumes used and final pressure histOry 14. Representative Daily Average Production or InjeCtion Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 101 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ Shut-in - 62 0 16. Status of well classification as: Oil ._~ Gas_ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ Bush Regional SignedGary ~ ~c~ ~'~, ~)~.~5~ Title Form 10-404 Rev ;~5/88k-~ Service Drilling Manager Date ~ 12-.-I I °l1 SUBMIT IN DUPLICATE UNOC2 SHEET A W~Z.R~RD PAGE NO. LEASE MG$.State 17595 WELL NO. 17 FIELD Middle Ground Shoal LOCATION: Leg #4, Conductor #7 1982' FNL & 48~' FWL, Sec. 31. T9N Ri2W. SM ELEVATIONS: WATER DEPTH 102' PERMIT NO.85-217 SERIAL NO.50-133-20381RKB TO OCEAN FLOOR 203' TD 7,272' TVD 6.923' RKB TO MLW 101' DEVIATION (BHL) 335'FSL & 1019'FWL, RKB TO DRILL DECK 23.16' SEC. 31, T9N, Ri~W, SM COMPANY ENGINEER CHUDANOV, HARNESS, RKB TO PRODUCTION DECK GRAHAM ~ __SPUD DATE 02-~6-91 COMP DATE 03-11-91 CONTRACTOR ~..A,A~ RIG NO. 61 TYPE UNIT OI.ME 2000 DRILL PIPE DESCRIPTION 5-1/2" 15.5# E&S 39.16' CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 30" 266' DRIVEN 20" 94# BT&C K-55 630' CHT'D W/1338 SXS 13-3/8" 68# BT&C K-55 3237' CMT'D W/2700 SXS 9-5/8" 47# & 53.5# BT&C N-80 7232' CMT'D W/2100 SXS PERFORATING RECORD DATE 03/~3/91 03/0~/91 03/02/9] 12/20/85 12/20/85 1~/20/85 INTERVAL E.T.D. 6022'-6052' 6645' 6092'-6143' 6645' 6160'-6230' 6645' 6385'-6438' 6645' 6454'-6502' 6645' 65~8'-6568' 6645' 6581'-6607' 6645' 6645.5'-6647.5' 6650' 6663'-6683' 7180' 6700'-6727' 7180' 6788'-6800' 7180' REASON PRODUCTION PRODUCTION PRODUCTION PRODUCTION PRODUCTION PRODUCTION SQUEEZE DST DST DST PRESENT CONDITION SOZ'D W/200 SX$ CMT OPEN (GRAVEL PACK~ . OPEN (GRAVE~ PACK) OPEN (GRAVEL PACK) OPEN (GRAVEL PACK) OPEN (GRAVEL PACK) OPEN (GRAVEL PACK) SQZ'D W/200 SXS CMT ISOLATED BY CMTR~T ~ 6650' ISOLATED BY CMTR~T@ 6650' ISOLATED BY CMTRET @ 6650' DATE INTERVAL NET OIL INITIAL PRODUCTION CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS WELL HEAD ASSEMBLY TYPE: CAMERON IRON WORKS CASING HEAD: 20"SOW X 20" 2M HOUSING W/13-3/8" CSG PREP. TYPE "WF" CASING SPOOL: 20" 2M X 12" 3M SPOOL W/9-5/8" CSP PREP, TYPE "WF" TUBING HEAD: 12" 3M X 10" 5M DCB SPOOL W/2 EA 2" 5M OUTLETS TUBING HANGER: 3-1/2" NOMINAL DUALSPLITHANGERS. BUTT-DOWN. EU 8RD-UP TUBING HEAD TOP: 10" 5M ¢RX-54) MASTER VALVES: LS: 3" 5M WKM SS: 3" 5M WKM CHRISTMAS TREE TOP CONN: 3-1/2" EU 8RD DATE 02/26/91 02/27/91 02/28/91 03/01/91 03/02/91 MW 63 PCF 65 PCF 64 PCF 65 PCF 65 PCF PLATFORM BAKER 17595 WELL #17 (BA-17) WELL HISTORY PAGE 1 ETD 6650' COMMENTS BEGAN OPERATIONS ON BAKER #17 AT 0800 HR$ 2/26/91. SKID RIG FROM LEG #2 TO LEG #4 AND RIGGED UP LINES. 6650' COMPLETED RIG UP. KILLED WELL BY PUMPING FIW DOWN L.S. AND UP ANNULUS AND THEN UP S.S. WELL BEGAN TAKING FLUID. INST. BPV'S AND REMOVED TREE. INSTALLED BOP. COULD NOT TEST BOE DUE TO LACK OF 2-WAY CHECK VALVES. FUNCTION TESTED BOE. REMOVED BPV'S AND R.U. TO PULL DUAL COMPLETION. PULLED TBG HANGERS AND SPOTTED SIZED SALT PILL. BULLHEADED PILL INTO PERFS. 6650' PULLED AND LAID DOWN 3-1/2" KOBE COMPLETION. COUPLINGS IN UPPER PORTION OF HOLE HAVE SEVERE CORROSION EXTERNALLY. REMOVED DUAL 3-1/2" RAM AND INSTALLED SINGLE 3-1/2" RAMS. TESTED BOPE TO 300 PSi AND 3000 PSI. FUNCTION TESTED KOOMEY UNIT. RIH W/8-3/8" BIT ON 9-5/8" CSG SCRAPER WHILE PICKING UP 3-1/2" D.P. 6650' CONTINUED TO RUN IN WITH BIT AND SCRAPER. TAGGED FILL AT 6444' DPM AND CLEANED OUT TO 6650' ETD. CIRCULATED WELL CLEAN AND PULLED OUT. RIGGED UP WIRELINE AND RAN CBL LOG FROM 6650' TO 3600' WLM. RIGGED DOWN WIRELINE. RAN IN WITH RTTS PACKER AND SET SAME AT 6620' DPM. TESTED THE ISOLATION RETAINER AT 6650' TO 2500 PSI FOR 15 MINUTES. PULLED UP AND RESET PACKER AT 6017'. PRESSURE TESTED THE CASING TO 3000 PSI FOR 15 MINUTES. RELEASED PACKER AND PULLED OUT OF HOLE. 6645' FINISHED PULLING OUT WITH RTTS PACKER. RIGGED UP WIRELINE AND RAN IN WITH PERFORATING GUN. TAGGED FILL HIGH AT 6636' WLM. PULLED OUT WITH GUN AND RIGGED DOWN WIRELINE. RAN IN WITH BIT ON 3-1/2" DRILL PIPE AND CLEANED OUT FILL TO 6656' DPM ETD (RETAINER). RIGGED UP WIRELINE AND RAN IN WITH PERFORATING GUN. SHOT SQUEEZE HOLES AT 4 HPF FROM 6645.5' TO 6647.5' WLM. PULLED OUT AND RIGGED DOWN WIRELINE. RAN IN WITH EZSV CEMENT RETAINER ON 3-1/2" DRILL PIPE. SET RETAINER AT 6645' DPM (6637' WLM). SQUEEZED THE "D" ZONE WITH 200 SXS "G" CEMENT WITH ADDITIVES MIXED TO 15,8 PPG SLURRY. FINAL SQUEEZED PRESSURE WAS 3250 PS! AT 2-3/4" BPM. CEMENT IN PLACE AT 1957 HOURS. LEFT 13 SXS CEMENT ON TOP OF THE RETAINER. TRIP FOR EZSV CEMENT RETAINER. DATE 03/03/91 03/04/91 03/05/91 03/06/91 Mw 65 PCF 65 PCF 65 PCF 65 PCF PLATFORM BAKER 17595 WELL #17 (BA-17) WELL HISTORY _ PAGE 2 ETD 6645' COMMENTS COMPLETED TRIP FOR EZSV CEMENT RETAINER. SET RETAINER AT 6080' DPM AS A Boq-rOM TO SQUEEZE AGAINST TO ISOLATE THE "A-6" SAND. TRIP FOR EZSV CEMENT RETAINER. SET RETAINER AT 5972' DPM. RIGGED UP TO SQUEEZE THE "A-6" ZONE PERFORATIONS FROM 6022' TO 6052' D~L. TESTED SURFACE LINES AND EQUIPMENT TO 5000 PSI. BROKE DOWN THE FORMATION WITH 700 PSI. INJECTED AT A 3 BPM RATE WITH 1900 PSI. MIXED AND PUMPED 200 SXS "G" CEMENT WITH ADDITIVES MIXED TO 15.8 PPG SLURRY. CEMENT IN PLACE AT 0800 HOURS. LEFT 10 SXS CEMENT ON TOP OF RETAINER. TRIPPED FOR BIT. RAN IN TO 5700' DPM. WAITED ON CEMENT TO 2400 HOURS. 6645' (CMT RET) CONTINUED IN FROM 5700' DPM AND TAGGED CEMENT AT 5955' DPM. CLEANED OUT GOOD CEMENT TO THE RETAINER AT 5972' DPM. DRILLED THE RETAINER AND CLEANED OUT CEMENT TO THE DRILLABLE BRIDGE PLUG AT 6080' DPM. TESTED THE SQUEEZED '%-6" PERFORATIONS TO 1500 PSI. LEAKED OFF 245 PSI IN 26 MINUTES. DRILLED THE BRIDGE PLUG AT 6080' DPM. PUSHED RETAINER JUNK TO 6475' DPM AND TAGGED THE CEMENT FROM SQUEEZE #1. CLEANED OUT JUNK AND CEMENT TO 6634' DPM. TRIPPED FOR NEW BIT. CLEANED OUT CEMENT TO THE RETAINER AT 6645' DPM. CIRCULATED THE WELL CLEAN AND PULLED OUT OF THE HOLE. 6645' (CMT RET) CONTINUED THE TRIP OUT WITH THE CLEAN OUT ASSEMBLY. RIGGED UP TO RUN TUBING. RAN IN HOLE PICKING UP 3-1/2" 9.2# N-80 TDS TUBING TO 6645' TM. CHANGED WELL OVER FOR PERFORATING AS FOLLOWS: PUMPED 100 BBLS FIW WITH 55 GALLONS OF "DIRT MAGNET"; PUMPED ONE WELL BORE VOLUME OF 3% KCL/FIW BRINE; RIGGED UP FILTER, CIRCULATED AND FILTERED BRINE TO LESS THAN 100 NTU'S AT THE FLOWLINE RETURN. TRIP FOR PERFORATING ASSEMBLY. 6645' (CMT RET) CONTINUED PULLING OUT OF HOLE STANDING BACK THE TUBING. MADE UP PERFORATING TEST HEAD ASSEMBLY. MADE UP TUBING CONVEYED PERFORATING ASSEMBLY AND RAN IN HOLE ON 3- 1/2" DRILLPIPE, FILLING WITH 3% KCL/FIW FOR A 500 PSI UNDERBALANCE. RIGGED UP WIRELINE AND RAN CORRELATION LOG. SET PERFORATING PACKER AND RAN CONFIRMATION LOG. RIGGED DOWN WIRELINE. RIGGED UP SURFACE LINES AND TESTED TO 2500 PS1. SHOT FLUID LEVEL TO PLATFORM BAKER 17595 WELL #17 (BA-17) WELL HISTORY PAGE 3 DATE MW E-~'. D, COMMENTS 03/06/91 (CONT) CONFIRM UNDERBALANCE. OPENED THE OMNI VALVE AND FIRED THE GUNS AT 1500 HOURS. PERFORATED THE WELL WITH 32 GRAM CHARGES AT 12 HPF (6 HPF "BIG HOLE", 6 HPF "DEEP PENETRATING") AS FOLLOWS: 6092'-6143' DIL; 6160'-6230' DIL; 6387'-6438' DIL; 6454'-6502' DIL; 6518'-6568' DIL; 6581'-6607' DIL. CYCLED THE OMNI VALVE TO THE REVERSING POSITION AND REVERSED DRILL PIPE CLEAN. RELEASED PACKER AND CIRCULATED WELL CLEAN. WELL TAKING 10 BPH FLUID. RIGGED DOWN SURFACE LINES AND PULLED OUT OF HOLE. 03/07/91 65PCF 6645' (CMT RET) RE EI /Eb APR 2 199! .0il & ~as Cons. Commission Anchorage 03/08/91 65 PCF 6645' (CMT RET) LAID DOWN PERFORATING ASSEMBLY. MADE UP BIT AND SCRAPER AND RAN IN HOLE TO 6645' DPM. CIRCULATED AND FILTERED FLUID FOR THE GRAVEL PACK. TRIP FOR GRAVEL PACK SUMP PACKER. PULL WEAR BUSHING, SET TEST PLUG, AND TEST BOPE. MADE UP BAKER MODEL "D" SUMP PACKER ON 3-1/2" DRILL PIPE AND RAN IN HOLE. SET PACKER AT 6620' DIL. TRIP FOR GRAVEL PACK LINER ASSEMBLY. MADE UP GRAVEL PACK LINER ASSEMBLY. FINISHED PICKING UP GRAVEL PACK LINER ASSEMBLY AND RAN IN HOLE ON 3-1/2" TDS TUBING. TAGGED THE SUMP PACKER AT 6620' DIL AND LATCHED INTO SAME. RIGGED SURFACE LINES AND PRESSURE TESTED TO 4000 PSI. DROPPED BALL AND SET BAKER SC1-L PACKER. TOPS OF 5.5" OD LINER ASSEMBLY AS FOLLOWS (DIL): SUMP PACKER AT 6620'; SNAP LATCH SEAL ASSEMBLY AT 6618'; WIRE WRAPPED SCREEN FROM 6611' TO 6060'; BLANK PIPE FROM 6060' TO 5925'; SLIDING SLEEVE AT 5900'; AND TOP OF SC 1-L PACKER AT 5891'. ESTABLISHED A CIRCULATING PRESSURE OF 200 PSI. GRAVEL PACKED THE LINER AS FOLLOWS: 10 BBL HEC GEL PREPAD; 165 FT3 20-40 OTTAWA GRAVEL MIXED WITH GEL TO A 10#/GAL SLURRY; 5 BBL HEC GAL AFTER PAD; AND 39 BBL COMPLETION FLUID DISPLACEMENT. SANDED OUT AT 2100 PSI. REVERSED OUT 14FT3 OF SAND SLURRY. 151 FT3 SAND IN PLACE BEHIND THE LINER (118% THEORETICAL). RETESTED THE PACK TO 1500 PSI AFTER 2 HOURS. CLOSED AND TESTED THE PORT COLLAR TO 1500 PSI. RIGGED DOWN SURFACE LINES AND PULLED OUT OF HOLE WITH GRAVEL PACK TOOLS. RIGGED UP WIRELINE AND RAN GP EVALUATION LOG. LOG SHOWED GOOD PACK. PLATFORM BAKER 17595 WELL #17 (BA-17) WELL HISTORY DATE MW ETD 03/09/91 65PCF 6645' (CUT RET) 03/10/91 65 POF 6645' (CMT RET) 03/11/91 PAGE 4 COMMENTS RIGGED DOWN WIRELINE. RAN IN HOLE WITH OEDP. PULLED OUT OF HOLE LAYING DOWN DRILL PIPE. RIGGED TO RUN 3-1/2" 9.2# L-80 TDS TUBING. RAN IN HOLE PICKING UP TUBING FOR SHORT STRING OF PRODUCTION COMPLETION. PULLED OUT OF HOLE STANDING BACK TUBING CHANGED TOP PIPE RAMS TO 3-1/2" DUAL RAM BLOCKS. PULLED WEAR BUSHING AND SET TEST PLUG. TESTED DUAL RAMS TO 3000 PSI. TESTED KOBE CAVITY ON THE DECK. RIGGED TO RUN DUAL 3-1/2" PRODUCTION COMPLETION. MADE UP KOBE CAVITY AND RAN IN HOLE ON 3-1/2" DUAL TUBING, HYDROTESTING TO 5000 PSI. INSTALLED HANGERS AND LANDED COMPLETION AS FOLLOWS: RE-ENTRY GUIDE AT 5849' TM; STANDING VALVE SEAT AT 5836' TM; KOBE CAVITY TOP AT 5814' TM. PACKED OFF DUAL SPLIT HANGERS. INSTALLED BACKPRESSURE VALVES. REMOVED BOPE. INSTALLED DUAL PRODUCTION TREE AND TESTED SAME TO 5000 PSI. INSTALLED 4 WAY VALVE MANIFOLD. LOADED STANDING VALVE AND PUMP INTO THE LONG STRING. DISPLACED THE PUMP INTO THE KOBE CAVITY WITH POWER OIL. 65 PCF 6645' (CMT RET) CONFIRMED PUMP WAS PRODUCING FLUID. SKID RIG TO LEG #2. HOOKED UP SERVICE LINES. RELEASED RIG. AT 1230 HOURS ON 3/11/91 TO ADL 17595 #13. 3-1/2", FROM 5848.38 5847.63 5837.83 5836.60 5813.95 5813.66 5803.60 5709.52 5706.37 32.30 31.80 31.00 9.2#, TO 5847. 5837. 5836. 5813. 5813. 5803. 5709. 5706. 32. 31. 31. 0. TUBING DETAIL BAKER PLT ," N-80 TDS TUBING WITH SP CL COUPLINGS~¢~: C0~;~/~.~,._ LONG STRING LENGTH JOINTS DESCRIPTION 63 0.75 WIRELINE RE-ENTRY GUIDE 83 10.55 PUP 3-1/2" 9.2# TDS 60 1.23 3-1/2" EUE x 3-1/2" 95 22.65 3" KOBE "B" CAVITY 66 0.29 3-1/2" TDS x 3-1/2" EUE XO 60 !0.06 PUP 3-1/~'', ~ 9.2# TDS 52 94.08 3 3-1/2" 9.2# TDS 37 3.15 PUP 3-1/2" 9.2# TDS 30 5674.07 182 3-1/2" 9.2# TDS 80 0.50 3-1/2" BUTT x 3-1/2" 00 0.80 CIW TBG HANGER 00 31.00 LANDED BELOW ZERO BUTT XO TDS XO FROM 5815.42 5805.26 5803.95 5710.13 5707.03 32.80 31.80 31.00 58 58 57 57 SHORT STRING TO LENGTH JOINTS DESCRIPTION 05.26 10.16 PUP 2-3/8" 4.6# N-80 EUE 8RD 03.95 1.31 3-1/2" TDS x 2-3/8" EUE XO 10.13 93.82 3 3-1/2" 9.2# N-80 TDS 07.03 3.10 PUP 3-1/2" 9.2# N-80 TDS 32.80 5674.23 182 3-1/2" 9.2# N-80 TDS 31.80 1.00 3-1/2" BUTT x 3-1/2" TDS XO 31.00 0.80 CIW TBG HANGER 0.00 31.00 LANDED BELOW ZERO NOTES: SHORT STRING LANDED 1.47' LONGER THAN LONG STRING TO PUT LS IN TENSION . CIW HANGERS ARE 3-1/2" BUTT-DOWN, 3-1/2" EUE 8RD-UP TOP OF KOBE BHA AT 5815.42' TM 3/8 88~ ~ 3237 .._ BAK~ SC-1 PACKER AT 58gOdil 5.5 15.5f ~ .012' WIRE WRAP ~VEI. PACKED 20-40 ME~-I O'i'i'AWA ~AND BAKER MODEL D SUMP PACKER AT 6620d;I .._ I' I ! 171 BAKER #17 L 05/10/91 CIW DUAL HNG 3.5 8rd TOP BUTT BTU __ 3.5 BUTr BY TDS CROSS OVER ~.5 9.2J N-80 TDS TUBII~ 3.5 9.23 N-80 TDS PUP 3.5 9.2~t N-80 TDS TUB 3.5 9.24 N-80 TDS PUP 3.5 TOS BY 3.5 EUE 8rnd CROSS OVER 8 KOBE PUMP CAVITY "B" g 3.5 EUE 8rnd BY 3.5 TDS CROSS OVER 10 3.5 9.2t N-80 TDS PUP 11 WIRE LINE REENTRY GUIDE ID 3" OD 5.5" SHOE OF WIRE LINE REENTRY SHORT STRING A CIW 3.5 DUN.. ~R BUIT BTM 8rd TOP B 3.5" BUTt BY 3.5" '/DS CROSS OVER C 3.5' g.2~ N-80 TDS TUBING D 5.5" 9.2tll N-a0 TDS PUP E 5.5' 9.2tlt N-80 TUB F ;~.5" 'IDS BY 2 3/'8 EUE 8rnd CROSS OVER G 2 3/8" EUE 8md PUP TOP OF KOBE CAVITY (SS LANDED 1.47 LONGER) TOPS 31 31.8 32.3, 57O6.37 5709.52 5803.6 5813.66 5813.95 5836.60 5837.85 5847.63 5848.38 TOPS 31 31.8 32.8 5707.03 5710.13 58O3.95 5805.26 5815.42 SS LANDED 1.47 LONGER TO ADD TENSION TO LS DRILLING FOREMAN EVAN K. HARNESS BAKER SC-1 PKR · 5891' BAKER WELD SCREEN GRAVEL PACK 20-40 MESH OTTAWA SAND BAKER SUMP PKR · 5520' CMT RET ~ 6645' CAST IRON BP · 6650' TUBING DETAIL LONG STRING (POWER FLUID) 1) CiW TUBING HANGER (BUTT) · ;31.00' 2) 3-1/2 BUTT PIN x ,3-1/2" TD$ PIN · ,31.e0 .3) 3-1/2" 9,2F N-80 TOS W/SP CL CPi. OS 4) ,3-1/2" 9.2# N-80 TOS PUP · 5706.;37' 5) ;3-1/2 TDS BOX x ,3-1/2 [U 8RD PIN 6) ,3-1/2 EU &RD BOX x ;3-1/2 TDS PIN · 58;36.60' 7) ;3-1/2" 9.2~ N-eO TOS PUP · 8e,37.e;3' 8) ;3-1/2- TDS BOX RE-ENTRY GUIDE · 5847.6;3' 9) KOBE 3" MODEL "B" BI-lA · 581;3.95' SHORT STRING (PRODUCTION) A) ClW TUBINO HANOER (BUTT) B) ,3-1/2 BUTT PIN x ;3-1/2" TD$ PIN · ;31.80' C) ;3-1/2" 9.2# N-a0 TOS W/SP CL CPLOS D) 3-1/2- 9.2~ N-aO TOS PUP · 5707.03' ~ 3-1/2 TD$ BOX x 2-3/8 ELI &RD PIN · 5803.95' F) 2-3/8 E:U 8RD PUl= · 5605.26' SQZ'D "A-6"'SAND PERFORATIONS 6022'- 6052' "BCD" ZONE INTERVALS 6092'- 6143' 6160'- 62.30' 6;385'- 64;38' 6454'- 6502' 6518'- 6568' 6581'- 6607' SOZ PERFS F/ 6645.5'- 6647,5' SOZD WITH 200 SXS CMT "D" ZONE INTERVALS 6663'- 6683' 6700'- 6727' 6788'- 6800' ADL 17595 WELL NO. 17 COMPLETION SCHEMATIC UNION Oil COMPANY Of CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 4-01-91 1 ¢---1 .~1; '/v "zooo March 14, 1991 Baroid Drilling Fluids, Inc. Mr. Don Chudanov Unocal Oil & Gas Division P.O. Box 190247 Anchorage, Alaska 99519-0247 Re: Baker Platform - BA-17 Workover Dear Mr. Chudanov: The material usage and costs for the above referenced well are broken down as follows: Sodium Chloride Potassium Chloride Miscellaneous Salts $ 1,311.60 $ 5,777.64 $ 317.76 Total Salt Cost - $ 7,407.00 Litesal Products (Pill) - $ 8,414.31 Polymer (XC, HEC) - $ 4,083.68 Total Products Cost - $19,904.99 Technical Service - $ 5,670.00 Miscellaneous Charges - $ 610.00 Total Well Cost - $26,185.39 In addition to the cost breakdown an itemized material usage and cost sheet is enclosed. For specific details involving the fluid during the operation please refer to the enclosed recap. The total cumulative volume lost the hole throughout this operation was 1,059 barrels. If you have any questions or require any additional information please do not hesitate to contact me. Sincerely, BAROID DRILLING FLUIDS, INC. T. Jay Olive Technical Sales Representative Attachment 2000 West Int'l. Airport Road, Suite A-10 * Anchorage, Alaska 99502 (907) 248-3511 · Fax (907) 248-5390 Unocal Oil & Gas Division BA-17 Workover Material Usage and Cost MATERIAL UNIT USAGE COST/UNIT AMOUNT Ammonium Chloride Baravis Barazan Calcium Chloride FL-7 Liteplug Liteplug-F Liteplug-X Litesal-XCP Potassium Chloride Salt TOTAL PRODUCT COST Technical Service Kenai Borough Tax Roundtrip Airfare Restocking Charge 66 LBS 3 $ 47.52 50 LBS 5 $135.58 50 LBS 9 $378.42 80 LBS 5 $ 35.04 50 LBS 1 $ 68.50 50 LBS 34 $ 65.05 50 LBS 34 $ 65.05 50 LBS 31 $ 65.05 50 LBS 22 $ 86.63 100 LBS 198 $ 29.18 80 LBS 120 $ 10.93 to Kenai 14 $405.00 4 $ 10.00 2 $111.00 1 $384.40 $ 142.56 $ 677.90 $ 3,405.78 $ 175.20 $ 68.50 $ 2,211.70 $ 2,211.70 $ 2,016.55 $ 1,905.86 $ 5,777.64 $ 1,311.60~ $19,904.99 $ 5,670.00 $ 40.00 $ 222.00 $ 348.40 TOTAL WELL COST $26,185.39 Unocal Oil & Gas Division BA-17 Workover Delivery Charqes: Ticket Numbers: Z34756 Z34757 Z34758 Z34765-02 Z34782-02 Z34768 Z34780 Z34801 Amount: $19,283. 12 $11,640.81 $22,727. 12 $ 5,995.20 916,787.94 $ 5,233.22 $ 1,225.00 $ 4~ 687.00 Total Charges $87,579.41 Cred i t s: Z34763-02 Z34791-04 Z34792-02 Z34804 Z34805 $ 5,246.40 $25,392. 12 $ 2,480.38 $19,364.38 $ 8,910.74 Total Credits - $61,394.02 Total Well Cost - $26, 185.39 Drilling Mud Record Petroleum Services COMPANY Unocal Oil & Gas Division WELL BA-17 Workover CONTRACTOR Baker P1 atform STOCKPOINT Rig Tenders Dock DATE 3/11/91 STATE A1 aska CASING PROGRAM inch at ft. COUNTY Kenai inch at ft. LOCATION Cook Inlet SEC TWP RNG inch at ft. BAROID ENGINEER Thomas, WO1 fe TOTAL DEPTH ft. DATE DEPTH NEIGHT VISCOSITY Yp GELS FILTRATION RETORT SAND CEC pH FILTRATION ANALYSIS ~ bs/ Sec APl PV 10 sec/ mi HTHP Cake Solids Oil Water Mud Strip )~ Pm Pf/ CI CA REMARKS AND TREATMENT feet % P,/P2 1991 cu fl . __°F _°F 10 min APl __°F 32nds % % % me/mt Meter [] Uf ppm ppm (See Operations Sheet) 2-26 64.8 7.5 !6000 Rig up well #1~ 2-27 · 2-28 5985 64 7.5 23000 Pickup BHA( ] ~ 3-1 6654 65 8.0 27000 RIH to test cs( 3-2 6645 65 7.0 27000 Squeeze, TOH 3-3 6645 :65 8.0 28000 Squeeze cmt, W( 3-4 6645 65 8.0 27000 RIH drill out retainer to 66z 3-5 6645 65 7.5 26000 Build volume 3-6 6645 65 7.5 26000 Circ out gas, 3-7 6645 65 7.5 26000 RIH circ thru 3-8 6645 65 7.5 27000 RIH wi th drl p' 3-9 6645 65 7.5 26500 POH laying dn pipe 3-10 65 7.5 27000 Landed tbg, ni~ up X-tree 3-11 F]LTE~ED iNLET WI.TER Filled pits wi' FIW, move rig Unocal Oil & Gas Division BA-17 Workover OPERATIONS D~TE ~ R~T ! ~ 2-26-91 Move rig to LEG #4, Rig up on Well #17. 2-27 2-28 3-1 3-2 3-3 3-4 3-5 3=6 3-7 3-8 No report available. Lay down 3 1/2" dual string tubing, pick up BHA and 3 1/2" DP. RIH w/8 3/8" bit and 3 1/2" DP, tag fill · 6444', clean out to 6654', circulate well clean, TOH, pick up test packer, RIH to test casing. TOH w/test packer, RIH w/bond log, RIH circulate well clean to run perforating gun on wireline, RIH w/cement packer, squeeze, TOH. RIH, set packer, TOH, RIH w/cement packer, squeeze cement, WOC. RIH, drill out retainer to 6645'. Clean #1 pit, clean shaker tanks, build volume, pump Dirt Magnet, circulate thru baker, filter unit. POH w/9 5/8" casing scraper, pick up perf assembly, RIH w/3 1/2" DP run correlation log, perf, reverse out, circulate out gas, TOH, daily losses 143, cumulative 547. Lay down guns, PU BHA, RIH, circulate thru Baker filter unit, POH, test BOPE, PU sump packer, RIH, set packer, circulate thru Baker filter unit, POH, PU gravel pack screens, RIH. Daily losses 219, cumulative 866. Completed gravel pack, POH w/tubing, rig up loggers RIW w/logs, POW w/logs, pd rigged down, RIH w/drill pipe will lay down, daily losses 83, cumulative 949. i~4ROID DRZLLZI~I~ I=I-UZD9, INC. Page 2 Unocal Oil & Gas Division Operations BA-17 Workover D~TE C~EIU~T I OHS 3-9 3-10 3-11 POH laying down drill pipe, RIH with one string of 3 1/2" tubing, POH standing back 3 1/2" tubing, will run dual string completion when hole string are stood back. Lost to hole 100, cumulative total 1059. Landed tubing, nippled up Christmas tree, dropped pump, moving rig to Baker well No. 13. Moved rig from Workover 17 to Workover 13, filled pits with Filtered Inlet Water. R~CIRGID DRII-I. II~B ~L, LJlDg~ INC~. s'r^'r .0 j co s v^'no APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Alter casing ~ Repair well __ Change approved program ~ Pulltubing X. Variance __ 2. Name..Qf O,oeratorA, .. ( UNOCAL ) j ..5. Type of Well: union Ull Company of California Development_~...~ / Exploratory __ 3'Addre'~.O. Box 190247, Anch., AK, 99519-0§ty~t'~rap.hic- / bervlce __ 4. Location of well at surface Leg #4, Conductor #7, Baker Platfoz Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Perforate ~ Other 34 7. U ~tjl~r .q3~.mej_ 7 5 9 5 m8. Well number 1982' FNL & 481' FWL, Sec. 31, T9N, R12W, SM At top of productive interval 6022 ' MD ( 5746 ' TVD ) 529' FNL & 814' FWL, Sec. 31, T9N, R12W, SM At effective depth 6 6 5 0 ' MD ( 6 3 5 4 ' TVD ) 420' FNL & 927' FWL, Sec. 31, T9N, R12W, SM At total depth 7 2 3 2 ' MD ( 6 9 2 3 ' rl'5]'D ) 335' FNL & 1019' FWL, Sec. 31, T9N, R12W, SM Well No. 9. Permitnumber 85-217 17 10. APl number 50-- 733-20381 11. Field/Pool Mid. Ground Shoal feet 12. Present well condition summary Total depth: measured true vertical 7232' 6923 ' feet Plugs (measured) feet Effective depth: measured true vertical 6650' feet 6354' feet RECEIVED Casing Length Structural 266 ' Conductor 630 ' 3237' Surface Intermediate 7232 ' Production Liner Perforation depth: measured Size 30" 20" 13-3/8" 9-5/8" Junk(measured) FEB. I ,5 199i ~las~.O/! .& 6as Cons. Commission Cemented Measured de~llOrage True vertical depth Driven 266 ' 266' 1338 sxs 630' 630' 2700 sxs 3237' 3155' 2100 sxs 7232' 6923' true vertical See attached Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2" 9.2# N-80 Butt None tubing LS @ 6022' TM SS @ 5959' TM 13. Attachments Description summary of proposal X. Detailed operations program __ BOP sketch 14. Estimated date for commencing operation February 21, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby certify th~,the forego~g is t. rJ. Le and correct to the best of my knowledge: Signed G~.~,c:~,_B~gSX~Z::~~/~t 4:_ I~ Title REGIONAL DRILLING MAN~..R ¢,3.-t ,..%_~ \ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witnessII Approval N o: ,~,/._,¢ ~)--~ Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- /¢-~/¢ Approved by order of the Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. _q~TU OO91 ' ~ Date R'-~(~)"- ¢ SUBMIT IN TRIPLICATE PERFORATION RECORD WELL ADL 17595 {17 (BA-17) 2/12/91 MEASURED DEPTH TRUE VERTICAL DEPTH PRESENT CONDITION 6022'-6052' 6104'-6130' 6162'-6220' 6385'-6430' 6455'-6472' 6483'-6500' 6519'-6562' 6582'-6600' 6663'-6683' 6700'-6727' 6788'-6800' 5746'-5775' 5825'-5850' 5881'-5937' 6097'-6141' 6165'-6181' 6192'-6209' 6227'-6269' 6288'-6306' 6367'-6386' 6403'-6429' 6489'-6500' OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN ISOLATED BY BP ISOLATED BY BP ISOLATED BY BP Oil & Bas Cons. Commission Anchorage PROCEDURE WELL ADL 17595 #17 (BA-17) 2/12/91 i · · MOVE RIG OVER MGS 17595 #17, LEG #4, SLOT #7° KILL WELL WITH COMPLETION FLUID. · · INSTALL BPV'S, NIPPLE DOWN TREE, NIPPLE UP 5M BOPE· TEST BOPE AND CHOKE MANIFOLD TO 3000 PSI. · · CUT, PULL AND LAY DOWN DUAL KOBE PRODUCTION STRING. RUN BIT AND CLEAN OUT FILL TO CMT RET AT 6650' ETD° 7. RUN SCRAPER TO CMT RETAINER AT 6650' ETD. · · 10. 11. 12. 13. PRESSURE TEST 9-5/8" CASING WITH RTTS PACKER. SET CMT RETAINER AT 6075' AS A BOTTOM FOR SQZo SET RETAINER AT 6000' AND SQZ "A-6" SAND (30'). R ¢EiVED CLEAN OUT RETAINERS AND CEMENT TO 6650' ETD. FEB 1 § t991 Aiaska 0/1 & Gas Cons. Commission CHANGE OVER TO CLEAN COMPLETION FLUID· Anchorage PERFORATE "BCD" ZONE WITH TUBING CONVEYED GUNS· 14. RUN SCRAPER TO 6650' ETD. 15. SET SUMP PACKER AT 6620'° RUN 5.5" OD GRAVEL PACK LINER ASSEMBLY WITH TOP PACKER. 16. 17. GRAVEL PACK THE ZONE FROM 6104' TO 6600'. RUN DUAL KOBE PRODUCTION STRING WITH PUMP CAVITY AT 5985'° 18. REMOVE BOPE AND INSTALL TREE. 19. RETURN WELL TO PRODUCTION AND MOVE OFF. NOTE: SBHP ANTICIPATED TO BE 2550 PSI AT 5825' TVD· WORKOVER FLUID WILL BE 3% KCL/FIW WITH NACL AS REQUIRED FOR WELL CONTROL. BELL NIPPLE I FLOWLINE 3" KILL LINE WITH TWO 3" 5M VALVES I (J? ;J; KILL LINE FROM MUD PMP &: CEMENT UNIT 1`3-5/8" ,3000 PSI ANNULAR ! I I PIPE RAMS BLIND RAMS 1,.3-5/8" 3M FLANGE ADAPTER 5M x 5M 15-5/8" 5M FLANGE DOUBLE GATE 5M 13-5/8" 5M FLANGE i , I PIPE RAMS ! 1 4." CHOKE LINE WITH ONE REMOTE & 1 MANUAL 4" 5M VALVE (1) ,], I CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) 13-5/8" 5M FLANGE SINGLE GATE 5M 13-5/8". 5M FLANGE RISER I I I 10" 5M x 1`3-5/8" 5M ADAPTER CAMERON 5M SPOOL RECEIVED FEB I 5 t99I Alaska Oil & Gas Cons. Commissior~ Anchorage 15-5/8" DOPE 5M STACK BAK ER PLATFORM (TESTED @ ,3000 PSI) UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC APP'D: GSB SCALE: NONE DATE: 11/16/90 @ 3237' /~ BAKER SC-1 PKR @ 5950' BAKER WELD SCREEN GRAVEL PACK 20-40 MESH OTTAWA SAND BAKER SUMP PKR @ 6620' CAST IRON BP @ 6650' I KOBE BHA ] · · 9-5/8" 47 & 53.5~/~,~]~~X~'x'~- @ 7232' TUBING DETAIL LS: 3-1/2", 9.2#, N-80 TBG BT&C. SS: 3-1/2", 9.2#, N-80 TBG BT&C. 1) POWER FLUID STRING 2) PRODUCTION STRING 3) WlRELINE RE-ENTRY GUIDE @ 5945' 4) 5-1/2% 15.5#, J-55, 0.012" WIRE WRAPPED SCREEN SQZ'D "A-6" SAND PERFORATIONS 6022'- 6052' "BCD" ZONE INTERVALS 6104'- 6130' 6162'- 6220' 6385'- 6430' 6455'- 6472' 6483'- 6500' 6519'- 6562' 6582'- 6600' R[¢EiVED FEB I ,5 1991 Alaska 0il & Gas Cons. Commiss'~-~:~.~ Anchorage "D" ZONE INTERVALS 6663'- 6683' 6700'- 6727' 6788'- 6800' ADL 17595 WELL NO. 17 PROPOSED WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) DRAWN: DAC SCALE: NONE DATE: 1-06-91 Per*Jnent Dat~ Spud Date: Surfoc~ Location: Sub,urfaee Lecaflon: Elevation: PBD: ~lng: PerfomUonn: InlUol Potential: Initial Stimulation: R~.ervolr ~ Cored Intervole: DST Intervale and Resulte: Log Inventory: MIDDLE GROUND SHOAL ADL 17595 WELL NO. 17 KENN CONGLOMERATE PLATFORM BAKER Complstlon Reoord IJg 4, Slot 7 1982' FNL, 481° FtbL, 8ea. 31, TgN, R12W. S.U. 11) - 33~' FNL, 101g' FWL~ Sea. 31. TgN. R12W. S.Id. 7g.4' KB 7232' 6923' 6650' 6354' 20". g4~l K-55 Caelng ,el at 830° arb 1338 ~x cement ~o 13 3~", ~8~ K-55 ~elng ~t d 3237' ~l~ 2700 ~x cement to ~u~oce 9 ~", 47 and 53.5~ N-BO Coaln~ ae~ at 7232' wl~ 2100 ~. BCD: 8022-8052' ' 6104-8130' 8182-8220' 8385-8430' 8455-8472' 8483-8500' 8519-8562' 8582-8800' 8883-8883' 8700-8727' 8788-8800' 838 BOPD. 127BWPD. 228 UCFD. OOR 453 None None Interval, 6663-8883% 8700-6727'. 6788-$800': Open 5 rain. 51 30 rain. open g0 rain. SI 3.~ bm. BBBI Influx. Somplel caught had b'ece o11. 4-- 12. Recover tO00 co; H20. trace o11..4CF ga, In downhole ,ampler. 1231 pal. The Interval had water produoUon and a CIBP wa. let at 6850' DIL. SP. CAL. OR. CNL, CDL. OR Long Sbtng: 1. Cameron Dual 10" tubing hong.r 2. 3 1/2" Butb3~, N-80 tubing 3. 3 1/2" Butb-e~s and 3 1/2" 8RD XO 4. Kobe 3" b/pa 'A' OPF Cavity &4~-L227 w/ ext, J'G seol sleeve 5. 3 1/2" 8RD and 3 1/2" Buttress XO 8. 3 1/2" Buttme, pup 7. 3 1/2" Buttres, N-80 tubing 8. Mule.hoe Short String: A. 3 1/2" Buttress N-BO tubing B. 3 1/2" Buttrey. and 2 7/8" 6RD XO C. 2 7/8" 8RD tubing pup run 1 Dep~ 32' 5959' 5967' 5985' 5986' 5988' 6021' 6022' 5957' 5959' 5989' CIBP at 6650' PBD 6650' TO - : k ~ 2o" ~41 CSA 820' 13 3/8" 68f 6022' 6220' 6385' 6500' 6519' 6600' 6663' 6800' CSA 3237' Steve W. Souders Division Production Manager Amoco Production Company Northern Division 1670 Broadway P.O. Box 800 Denver, Colorado 80201 303-830-4040 January 6, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 File: MAG-101-WF Subsequent Notice MGS 17595 Well No. 17 Platform Baker, Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-404, Report of Sundry Well Operations to notify you of work recently completed on MGS 17595 Well No. 17. MDG/mar Attachment · Anc~0m~ a:mdgl01.d STATE OF ALASKA ALASK-.,--OI L AN D GAS CONSERVATION COMIW,,,-SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed' Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator Amoco Production Company 3. Address P. O. Box 800, Denver 4. Location of well at surface 1982' FNL 481; FWL, At top of productive interval 529' FNL, 814' FWL, At effective depth 6650 ' 420' FNL, 927' FWL, Colorado 80201 Leg 4, Slot 7, Platform Baker Sec. 31-T9N-R12W, S.M. 6022' MD, 5746.' TVD Sec. 31-T9N-R12W, S.M. MD, 6354' TVD Sec. 31-T9N-R12W, S.M. Attotaldepth 7232'MD, 69 335' FNL, 1019' FWL, 5. Datum elevation(DForKB) 79.4 KB 6. Unit or Property name MOS 17595 7. Well number 17 8. Approval number 7-923 9. APl number 50--733-20381 Feet 23' TVD Sec. 31-T9N-R12W, S.M. 10. Pool Middle Ground Shoa Field, Lower Kenai Cong. 11. Present well condition summary Total depth' measured true vertical 7232 feet 6923 feet Plugs (measured) Effective depth: measured 6650 true vertical 6254 feet feet Junk (measured) Casing Length Structural 266 ' Conductor 6 30 ' Surface 3237' Intermediate Production 7232 ' Size Cemented 30" Driven 20" 1338 sx 13--3/8" 2700 sx 9-5/8" 1100 sx Liner Perforation depth: measured See attached list Measured depth 266' 630' 3237' 7232' true vertical ~ue ~rtical depth 266' 630' 3163' 6923' ~bing(size, gradeand measureddepth) 3-1/2" N-80 BUTT TBG at 5984' PackersandSSSV(typeand measureddepth) None 12. Stimulation or cement squeeze summary None Intervals treated (measured) Treatment description including volumes used and final pressure Gas Cons. C0~r, missi0~ Anchorage 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 221 80 124 Casing Pressure 7O 7O 217 98 144 Tubing Pressure 75 7O 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Date Submit in Duplicate Perforations: Perforations open to production (MD + TVD) of top and bottom and interval. HO (Feet) 6,022 -.6,052 6,104 - 6,130 6,162 - 6,220 6,385 - 6,430 6,455 - 6,472 6,483 - 6,500 6,519 - 6,562 6,582 - 6,600 TVD (Feet) 5,746 - 5,775 5,825 - 5,850 5,881 - 5,937 6,097 - 6,141 6,165 - 6,181 6,192 - 6,209 6,227 - 6,269 6,288 - 6,306 Net Feet 30 26 58 45 17 17 43 18 W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-562-2147 December 1, 1987 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Attention' Mr. C. V. Chatterton, Chairman File' FEW-149-WF Application for Sundry Approval MGS 17595 Well No. 17 Platform Baker, Cook Inlet, Alaska Attached in duplicate is a State Form 10-403, Application for Sundry Approval, outlining plans to pull MGS 17595 Well No. 17 and replace the BHA due to a stuck pump. This Sundry was verbally approved on November 25, 1987. Operations were started on November 26, 1987 and we are currently placing this well back on production. Very truly yours, W. G. Smith District Manager Attachments KWU/dds Alask~ 0il & Gas Cons. Commission Anchorage STATE OF ALASKA AL ;A OIL AND GAS CONSERVATION CC.. ISSION APPLICATION FOR SUNDRY A'PPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension ~ Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate [] Other [] 2. Name of Operator Amoco Production Company 3. Address P.O. Box 100779, Anchorage, Alaska 99510 4. Location of well at surface Leg 4, Slot 7, Platform Baker 1982' FNL, 481' FWL, Sec. 31, T9N, R12W, S.M. At top of productive interval 6022' MD (5,746' TVD) .529' FNL, 814' FWL, Sec 31, T9N, R12W, S.M. At effectivedepth6,6501 MD (6,354' TVD) 420' FNL, 927-' FWL, Sec 31, T9N, R12W, S.M. 5. Datum elevation (DF or KB) 79.4' KB feet 6. Unit or Property name MGS 17595 7. Well number 17 At totaldepth 7,232 MD (6923' TVD) 335' FNL, 1019' FWL Sec. 31, T9N, R12W. S.M. 11. Present well condition summary Total depth: measured true vertical 7232 feet Plugs (measured) 6923 feet Effective depth: measured 6650 feet Junk (measured) true vertical 6354 feet 8. Permit number 85-217 9. APl number 5o- 733-20381 10_ Pool Middle Ground Shoal Lower Kenai Conglomerate Fi Casing Length Size Cemented Structural 266' 30" Driven Conductor 6301 20'l 1338 sx Surface 3237' 13 3/8" 2700 sx Intermediate Production 7232' 9 5/8" 1100 sx Liner Perforation depth: measured See Attached List true vertical Measured depth ~ue Vertical depth 266' 266' 630' 630' 3237' 3247' 7232 6923' RECEIVED DEC 0 ! !9S7 ~bing (size, grade and measured depth) 3~'' N80 BTC at 6531' 2 Packers and SSSV (type and measured depth) None Amska Oil & Gas Cons. Commission Anchorage 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation November 26, 1987 14. If proposal was verbally approved Name of approver Mr. ' Wondzel 1 1509 Hours Date approved 11/25 / 87 15. I here~ertify_ thatye foreg~;H~ ng is true and correct to the best of my knowledge Signed ( ~ ..,~"'/.¢,.'z.¢(~ ,~-'~'-~-~.,,' Title Di stri ct Manager Date 12/01/87 Conditions of approval Approved by Form 10-403 Rev 12-1-85 Commission Use Only : Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance[ -' Approved COpy ~ ~ ~ 0RIGINALLONNiE SISNEI:I BY __./,~'- ~ ~,4~%' by order of O. SMITH Commissioner the commission Date Submit in triplicate C ~v~-.. " Amoco Production Coml:'-*'t ~IVlOCO, ENGINEERING CHART /,/A,'E IL"' 3D©D tt ~ I · F~YDRIL / AN NDL/IR B,OP/J 1 LXN3 i ' t~F,P~ 3-'(f~ t. ! t - o,P L 300(0 '3Oo0 SHEET NO. OF FILE 'TO Lq "L,,,_~ ) Perforations: Perforations open to production (MD + TVD) of top and bottom and interval. MD (Feet) 6,022 - 6,052 6,104 - 6,130 6,162 - 6,220 6,385 - 6,430 6,455 - 6,472 6,483 - 6,500 6,519 - 6,562 6,582 - 6,600 TVD (Feet) 5,746 - 5,775 5,825 - 5,850 5,881 - 5,937 6,097 - 6,141 6,165 - 6,181 6,192 - 6,209 6,227 - 6,269 6,288 - 6,306 Net Feet 3O 26 58 45 17 17 43 18 Middle Ground Shoal 17595 No. 17 Description.Summary of Proposal 1. Displace well to power oil. Shut-in and determine kill weight. 2. Skid rig to Leg 4, Slot 7. 3. Kill well. RU lubricator and cut short string. 4. Set back-pressure valves (BPV's). ND tree. NU BOP's and test. Pull BP~'s. 5. Pull tubing and BHA. 6. Clean out to PBTD of 6,650 feet. 7. Run new BHA and tubing. 8. Set BPV's. ND BOP's. NU tree and test to 5,000 psi. Pull BPV's. 9. Run SV and pump and place well on production. DEC Alaska Oil & 6,as 6or~s. 6ommissio~ Anchorage W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 May 14, 1986 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Fi 1 e: FEW-130-WF Gentlemen: Well Completion Report Middle Ground Shoal 17595 Well No. 17 Platform Baker Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-407, Well Completion or Recompletion Report and Log for the subject well. A Directional Survey and a Well History are also attached for your information. Very truly yours, W. G. Smith Di strict Manager Attachment KWU/dds O08/engi ' "~-~' STATE OF ALASKA '~-~--- 0 RIG IN A L " ALASKA ~ .- AND GAS CONSERVATION C,.~ VIISSION WI=LL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL[] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number 85-217 Amoco Prodlmtinn Company 8. APl Number 3. Address P.O. Box 100'779, Anchorage, Alaska 99510 50-733-20381 4. Location of well at surface Leg 4,' Slot 7, MGS Platform Baker' 9. unit or LeaseUame 1982' FNL, 481' FNL, Sec. 3'1, TgN, R12W, S,M. HGS 17595 10. Well Number At Top Producing Interval B sand at 6,022 ND, 5746 TVD, 529' FNL, 814' FWL, Sec. 31, T9N, R12W, S.M. 17 AtlotalDepth 7,232 MD, 6,923' TVD, 3'35' FNL, 1019 FWL, Sec. 31 11. Field and Pool T9N, R12W, S.M. Middle Ground Shoal Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Lower Kenai C0ngl omerate 79.4' KB ADL 1759.5 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Complet,ons 11-12-85 12-14-85 ' 5-2-R6I 102 feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+iYD) 19. Directional Survey I 20. Depth whereSSSV set 21. Thickness of Permafrost 7,232 (6923) 6650 (6,354') YES~ NO []I N/A feet MD -0- 22. Type Electric or Other Logs Run See attached list. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 32(1 -- n ?~6 -- dri yen 20" 94 K55' 0' 630 26" 1338 sx to SFC 13 3/8" 68 K55 0 3237 17~" 2700 sx to SFC 9 5/8" ~7, 53.5' N80 0 7232 12~" 1100 sx 1st stg DVT at 4385 - 1000 sx 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) Dual 3..~" ~ ~_E31_ ' N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. SEE ATTACHED LIST DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED None 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 12-22-85 IFl~win~ l~f_ prnrll~rt-~nn F~n~led - I=lvdra~lirI~=f DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF 'W'~¥~EI~-BBL c~HoK-E-siZ'E- TG~A'S-"OILRATIO 04-30-86 6 TESTPERIOD ~ 130.7 46.2 ?F;.2 N/A 353 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 75 60 24-HOUR RATE I~ 522 185 101 34 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~,, :-,, ,~ ..... ~ .¢. ~ i , i,~~ None :~ ;' '~,~ ~-'! ~ Submit in duplicate~/ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ., - GEO'-LOGiC 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. T~v0nek "A" 55'2'8 527'0' See Attached Mi ddl e '"B" 59'70 56'96 Kenai "C" 635-3" 6066 Sands "D" 665'6· ' 636'0 "E" 17768 6762 : · 31. LIST OF ATTACHMENTS Logs, Perforation Summary, Chronnl~air. at Wmlt Fli~fnry ~nrl n~rf~l ~,,- ..... -- ! I j ....... :.......... II IV V I Vll'~l~ I J[ 1 32. I hereby certify that the foregoing-is true and correct to the best of my knowledge Signed ~(~v ~' ~ ~ Title ,F)i_~_rict Ma~erDate 05/ /~6 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 Show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". 22. Type electric or other logs run. Mud Log 1768-7232 feet Date Lo9 12-14-85 DIL, SP, CAL, GR 12-14-85 CNL, CDL, GR Interval 3230-7230 (GR to Surface) 3230-7230 24. Perforations open to production (MD + TVD) of top and bottom and interval, size and number). MD (Feet) TV.D (.Feet) Net Feet Size 6,022 - 6,052 5,746 - 5,775 30 .5 6,104 - 6,130 5,825 - 5,850 26 .5 6,162 - 6,220 5,881 - 5,937 58 .5 6,385 - 6,430 6,097 - 6,141 45 .5 6,455 - 6,472 6,165 - 6,181 17 .5 6,483 - 6,500 6,192 - 6,209 17 .5 6,519 - 6,562 6,227 - 6,269 43 .5 6,582 - 6,600 6,288 - 6,306 18 .5 All perforations shot 4SPF- 90° phase IAKKR SAND CONTROL A Baker Hughes company 4792 BUSINESS PARK BLVD. BUILDING F, SUITE 3 ANCHORAGE, ALASKA 99503 TELEPHONE (907) 563-0625 FAX NO.(907) 563-0385 Unocal Oil & Gas Division ?.0. Box 190247 Anchorage, Alaska 99519-0247 March 20, 1991 Attn: Don Chudanov Re: Completed Gravel Pack Summary Platform Baker's MGS 17595 # B-17 Baker Sand Control is pleased to submit this summary of the completed gravel pack on platform Baker's well B-17. SINGLE ZONE GRAVEL PACK Top Shot of Perforations at 6092' Bottom Shot of Perforations at 6607' Guns: Vann 6" (?) OD 8 shots per foot Sump Packer at 6620': Baker Model 'D' size 194-47 Lower Tell-Tale: 6' X 5-1/2" 0.012 gage Bakerweld Gravel Pack Screen: 549' X 5-1/2" 0.012 gage Bakerweld Gravel Pack Packer at 5890': Baker SC-1 size 96A2-47 Calculated Volume Placed: 128 cubic feet Actual Volume Placed: 151 cubic feet Gravel Pack Sand: 20-40 Baker Low Fine (in 10 ppg slurry) Pump Rate: 4 BPM Pump Pressure: 200 PSI Fluids: Filtered with a D.E. Press to a 2 micron absolute Polymers: A Baker clean gel was mixed to yield a 350 cp viscosity. The gel was then cycled through a hydraulic hydrator to remove any micro-fisheyes. It was then filtered through a 25 Whatman filter paper. COST TOOLS (SALEABLE): TOOLS (RENTAL): FILTERING: PUMPING: $100,716.46 9,981.15 18,308.80 27,852.00 TOTAL: $156,858.41 Baker Sand Control would like to thank you for your business and we look forward to providing you with quality service and products in your upcoming gravel packing and perforating completions. Sincerely, DS:RR Baker Sand Control, a Division of ~__aker HuShe$~Production Tools Inc. Darryl ~ow Alaska gales Representative UNOCAL BAKER PLATFORM WELL NO. 1T DETAIL COMPLETION PROCEDURE FEBUARY 19, 1990 I , II. CASING TEST PROCEDURE 1. Move rig and rig up over the hole. Run in with Baker "EA" Cementer and test casing to 1500 psi for obtained then cement squeeze Retrievamatic packer 30 min. If no test is COMPLETION PROCEDURE . Pickup 3-1/2" PH-6 workstring and RIH casing scraper and wire brush for 9 6620' Change the completion fluid wellbore as follows: open ended with 5/8" casing to over in the Monitor turbidity readings wellbore during the entire as a function of time . important as whether or not of fluid coming out of the change over. Plot this data The actual reading is not as the reading are stable. A , Pump 100 bbl 12 to 13. C maximum "cri while circula s FIW and caustic soda spacer with a pH irculate the pill through the system at tical rate". Reciprocate the pipe ting. B. Mix and pump 60 bbls HEC-FIW spacer with 25#/bbl coarse frac sand. C. Mix and pump 200 bbls sweep containing FIW and one drum Dirt Magnet (4.2#/bbl). D. Circulate one wellbore volume of FIW at a maximum "critical rate" until clean. E. Reverse the tu attaine proceed contact F. Pump 40 circulate 1.5 workstring volumes. Measure rbidity of the fluid when "bottoms up" is d. If the Turbidity is less that 35 NTU's to step F. If greater than 35 NTU's the office. bbls HEC spacer. Page 2 III. G , H o Disp]ace the hole with 6 KCL, FIW and NaC) if ne density pumped equals the 4 pcf completion fluid eded for weight) until the density at the f)owline. Filter the completion fluid unit with a capacity of +/- micron absolute filter until 35 NTU's on a turbidity meter. with a Baker DE filter 4 bpm followed by a 2 returns are less than , Make shoot up Van tubing cony 8 spf. Perforate the eyed perforating assembly to following zone: RIH with guns and p 500 psi drawdown whe (A-zone reservoir pre to psi). correlation. Pressur guns-primary (bar dro When guns fire, slow to allow formation f we))bore cleaning out t acker to +/- 6090'. Obtain a n the guns are to be fired ssure is estimated at Run gamma ray log for depth e the annulus to fire the p firing system as backup). ly and immediately open choke luid and debris to enter the he perforations. , Open the bypass and re clean. Circulate and adj required. POOH with the g verse circulate the workstring ust completion fluid weight as uns. , RIH with workstring, cl to 6050' and wait 2 hour fill is found spot a 5 Pill. POOH w/ worksting. ean out to PBTD 6850', pull up s. Run in and tag for fill. If 0 bbl Baker Cean self breaking 5. RIH with Model "D" Sump packer and set at 6613' DIL. Gravel Pack Comp)etlon 1. Pick up the gravel packing screen assembly as follows: A) Baker Model "S-22" snaplatch seal assembly, size 190-47, with two (2) additional seal units. B) 6' of 5-1/2" Baker-weld wire wrapped 0.012 gauge stainless stee] screen. C) 5 1/2" X 2 7/8" Baker O-ring seal sub. age 3 , . . D) 5~-~ of 5-1/2" Baker-weld wire wrapped 0.0.12 gauge stainless steel screen. Centralized for 9 5/8", 53.5#, J-55 casing, two-sets per joint. E) 128' of 5 I/2" blank liner. F) 2 7/8" polished stinger, 834' 2-7/8" tubing run concentrically inside the screen for tail pipe. G) Baker Model "S" Gravel pack extension with a sliding sleeve, size 190-47. H) Baker Model "SC-l" gravel pack packer, size 98A2-47. I) Baker Mode) "SC" I90-47 crossover too) with "SC" setting tool, size 88. Note: Items G thru I are picked up as one unit. Run out to into verify packer With bbls tubing the ba the gravel pack assembly the work string prior to obtain a safe working height at the sump packer and then depth. Snap latch sea) into the well slowly. Space snapping into the sump packer the rotary table. Snap snap back out again to assembly back into sump the workstring in the neutral position, circulate 10 of filtered brine at 2 bpm to insure ball seat and are clear of any potential debris prior to dropping 11. Drop the 1-7/I6" Kirksite setting ball and allow minutes for the bail to gravitate down. Set and test "SC-IL" packer. Release from the "SC-IL" packer actuating the hydraulic release and pick straight up. NOTE Shear the Bal)seat with the crossover tool in the reverse circulating position. 30 the by Position and test the circulating, and reverse injection and circulation crossover too) in the squeeze, circulating positions. Obtain rates. Page 4 . . With the crossover tool in the reverse circulating position, mix and pump at 3 bpm the following slurry volumes: A) 10 bbls 350 cps Baker HEC Ge) B) 48 bbls of slurry (140 cu gravel, mix at 10 ppg). C) 5 bbls 350 cps Baker HEC Gel Pre Pad ft of 20-40 Baker Iow fine after-pad When the pre-pa crossover tool in an 800 psi pressur the lower tell t crossover tool up reduce the rate continue pumping over circulating crossover tool circulate the work the "SC-IL" packer d reach to the l e increa ail scr into to 2 b until a pressure es the crossover tool, place ower circulating position. When se has been achieved (indicating een has been covered) pick the the upper circulating position, pm, choke the returns by 50Z and sand-out pressure of 1500 psi is obtained. Position the into the reverse position, reverse string clean. Pull crossover tool above and wait 3 hours. Lower the c position, res pressure. I achieved prey too] p)aced additiona] of I500 psi rossover tool into the upper circulating tress pack to 1500 psi over circulating f pack fails to test or a sand-out was not iously, remix and pump with the crossover in the upper circulating position an batch as determined, until a sand-out pressure over circulating pressure is achieved. 8. Rig up wireline and run gravel pack log (Photon Log). 9. If no voids are present, proceed with completion. If voids are present transmit logs and wait for instructions. 10. Install and test tree. Place well on gas lift. 11. Rig down and move off well. UNOCAL II\BAK 817 Cas Con~ UNOCAL BAI<ER B-17 FILTRATION REPORT 3/5/91 NTU'8 200 !50 FIIJ'ERII'~G 168 BBL,S FROM PIT I TO F,,.'!T 2 0 0500 0800 0'700 0800 0900 70.8 PPCF 3% t,,.£,t .... ,[''[' I II ./" FILTERING HOLE .............. BEFORE PERFOR^TING .............. --.... .... ................. - ............... _[:_.'_::. :..:..~_:~. ............... 1 .................. :.' ...... :. ............. ~._._:....,~_ .:~__:.:-.-.I,~__~:::::.-:.::~'..:.~' :_.L~_.~::.:.~::z~.:~:..~_:,~ 1000 1100 '1200 T'tME IN HOURS WELL OR PIT PRESS DISCHARGE UNOCAL BAKER B--17 FILYR^]~'ION REPOR'r 3/7/91 lO0 ~0 60 4O N TU'S 70.8 PPCF 3% KCL ', FIL[ERING WELL A,, "[ ER PERFORATING 0 0500 0600 07'00 0800 1600 170 0 '1800 TIME IN HOURS ............. %,~EI..L OR PIT' RETI,.JlRNS o$ DISCHARGE EQUIPMEN1 ..,d SERVICES LOCATIOH: ~PERA'[OR ' FAX# ~u~ BON CHUDANFIV / EVAN HARNESSW~LL i! MIDDLE GRBUN]B SHOAL B-17 ?'rATE LE. Aear )AT G NAWE PLATFDRH ~KEE E ~UB~O PHS i HARCH 8, t991 ~REPARED BY DARRYL SNOW ~H~ JOB # PH~ 563-0825 NO.! DEPTH LENGTH! O.D. I.D. i SAND CONTROL A Baker Hughes company I' sIZE CASING, .~ 5,'~' I LINER i TUBING I iWKSTRGt WEIGHT 53.5~ GRADE I THREAD 3 i/2' 9.2 N-80 ! T]3S LISTED BELOW !l:CIdP'FLUID IHHIBllOR I C,,OAIING ~ 5 1/2' .Or2 GAGE 120-40 BAKER LOV FIH[ :HP mgHI l~. O~. IZONE DESCRIPTION I k 5~90,66 8 5895.40 3 5700.65 4 5902.49 5 5903,P4 6 5925.00 7 5985.65 5957,89 5990.]1. 6.088.35 6054.57 6060,89 6~5~,36 6t9L~ 6~3.7~ 6352,88 6~7,g5 6481,74 ~513.97 6546,88 ~578.47 9 6610,77 lO 66tL79 " 6618,~ 12 ~6t8.75 i 13 ~0.00 INFO RWATION: 4.74 5,25 194 ,75 8t.76 32,84 32.84 38,88 5,72 3£.Ug ,-'0,i~0 20.~0 3P20 32.22 38,33 32.33 3P.81 32.83 32,23 38.18 38,87 3E.18 3~.~3 32,85 32.25 32,30 [ 6,~1 1.~5 3,50 9,250 6,875 7.00 6,25 G.75 7,375 5.50 · · · · 6,11 G.O0 6,11 6.OB 8.185 4,75 525 5.85 4,75 5,75 4.'95 4.95 · 4,95 · 8.875 4.95 ~,~5 4.75 76A8-47 .SO-[ GRAVEL PACK PACKER UPPER EXTENSION SLIDING SLEEVE SEAL ~ORE LOWER E×TENSIUN CROSSOVER ~UB 5 l/2' 17# BLANK PIPE BLANK PIPE ON TOP DF SCREEN .JOINT BAKERVELD GRAVEL PACK SCREEN SIZE 5 1/8' ,Or8 GA(][ O-RING SEAL SUB LOWER TELL-TALE .018 GAGE SCREEN CROSSOVER SUB SNAP LATCH SEAL ASSY. V/;:=' EXTRA SEALS MI]DEL 'D' SUMP PACKER SIZE 194-47 TOP SHOT AT 6092' BOTTOM SHOT AT 6607' Chronological Hi story Middle Ground Shoal 17595 Well No. 17, Platform Baker (November 1985) 11-12-85 to 11-14-85 11-14-85 11-15-85 11-16-85 to 11-18-85 to 11-21-85 11-22-85 11-23-85 11-24-85 to 11-25-85 11-26-85 to 11-27-85 11-28-85 to 11-30-85 Spud well and clean out 30-inch slot mud motor to 448 feet (17½-inch hole.). Drill to 630 feet and open hole to 26 inches. Run 20-inch casing to 630 feet and cement with 838 sx 12.6 ppg lead slurry and 500 sx 15.8 ppg tail slurry. Nipple up lO-inch diverter system and drill to 1,270 feet.. Kick-off with mud motor 1,270 - 1,768 feet. Drill 1,768 to 2,184 feet Mud motor 2,184 - 2,296 feet- Drill 2,296 - 3,240 feet Run 13 3/8" casing to 3,237 feet and cement with 2,200 sxs lead slurry and 500 sx tail slurry. Test casing to 1,500 psi. Run formation integrity test to 13.5 ppg EMW and drill to 4,434 feet Middle Ground Shoal 17595 Well No. 17, Platform Baker (December 1985) 12-01-85 to 12-03-85 Drilling 4,434 - 4,897 feet 12-03-85 to 12-05-85 Mud motor 4,897 - 5,189 feet 12-05-85 to 12-14-85 Drill 5,189 - 7,232 feet 12-15-85 Logging DIL, SP, CAL, GR CNL, CDL, GR 7,230 - 3,230 feet 7,230 - 3,230 feet 12-16-85 Run 9 5/8-inch casing and cement first stage with 1,100 sxs Class 'G'. 12-17-85 Cement second stage through "DV" tool at 4,385 feet with 1,000 sxs Class 'G'. 12-18-85 Drill out DV tool and clean out to 7,180 feet PBTD. Pres- sure test casing to 1,750 psi for 30 minutes - OK. 12-19-85 Run D~T_.on "D" sand. Perforate 6,663 - 6,683 feet, 6 700 - ~7 feet, 6,788- 6,800 feet. Open five minutes, ~I 30 minutes, open 90 minutes, SI 3.5 hours, 8 barrels influx. Reversed out 99 percent water with trace of oil. 12-20-85 Set CIBP at 6,650 feet MD. 12-21-85 Perforate "B" and "C" sands 6,022-6,052 feet, 6,104-6,130 feet, 6,162-6,220 feet, 6,385-6,430 feet, 6,455-6,472 feet, 6,483-6,500 feet, 6,519-6,562 feet, 6,582-6,600 feet, at 4 SPF. 12-22-85 Flowing well through drillpipe. Packer set at 5,980 feet - testing. 12-23-85 to 12-31-85 Flowing and testin§ well. Flow test on 12-30-85; 660 BOPD, 96 BWPD, 282 MCFD. Middle Ground Shoal 17595 Well No. 17 Platform Baker (January 1986) 01-01-86 to 01-05-86 01-05-86 to 01-10-86 01-11-86 01-12-86 01-13-86 to 01-31-86 F1 ow testing well Attempt to kill well with emulsified diesel. Could not kill well with 8.8 ppg fluid. Kill well with 9.4 ppg brine. Run dual 3½-inch tubing and Kobe 3-inch cavity. Release rig at 0600 hours. Seat pump. Pump test well. Four hour test 01-30-86 732 BOPD x 126 BWPD x 266 MCFD. 02-01-86 to 02-28-86 03-01-86 to 03-31-86 04-01-86 to 05-02-86 Middle Ground Shoal 17595 No. 17 Chronological History Pump test BC sands. Six hour test 02-14-86. 512 BOPD x 64 BWPD x 216 MCFD. Pump test BC sands. Average March production: 574 BOPD x 120 BWPD x 279 MCFD. Pump test BC sands. Well finaled May 2, 1986 as pumping oil well producing from the BC sands at 522 BOPD, 101BWPD and 185 MCFD. JOB INIT[ATIflN REP~RTt CD~PANY OPFR/tT~D - aECOI~PLETtON - DEVELOPMENT H~D~LE GRND'SHOALt-~ K~N~ O/S ~tnTFt aL~SK~ OPEaaTOR: a~OCC PR O~ ........................................ · . . ~ .... ~ ....... . ..... AUTH HORIZON ZONal 01 - MGS ttS~t 1~ ........................................... ....................................... , .................................. eee~ CaNTRACTOR(S) ZN~ORPAT~ON: PARKERt 0152~ RIG ~OVE ON [1/26/RT~ RIG aELEASED 11/30/8? .............. ,( MGS"I?$9~"I?f ~tDDLE GRND ~HOALf PA~KER'Z~2~ AMOCO PRODUCTtON~ ....... AMOC~ ~e~e RE~A~KS: OPF~AT~ON COmmENCeD 12 NOON CHPON TI~E ~STaIflUT~N "~ 2&-O0 -"~ "MO ~ ........... PElF L.$.- CIRC WELL DTD NOT GET RETURN5 F~OM WELL FLUI~ LEVEL' WaS 23~5 WHEN DONE C~RC-FLUI~ LEVEL ~aOPPED TO ~100 IN a H~S JO~ ~N~T~T~ON P~O~T: OT~£CT!ON~L HOL~ ............... CURn~NT WELL ~CTTV?~Y-CD~PLT-O~G~ .~,e~ .... 11/2S/87 .... .ee~ .................. MGS 175q5 17~ MIODLE GRND SHO~L~ PaRKEa 1~2~ AMOCO DaODUCTION~ FLOC '~6650~Ol-ae'aP~' 50~3~Z03~100. aU?-'TP 722qe ~UTH COST '~150000, ............... ~MOCO W. [~ OPERATIONS: TD 7232 cTe P~Tf. 6~22~ NIPPLE UP BOP%e FM DSL COSTS: DaZLY WELL ~22~86~ CUM WELL .............................................................. CHRON" T~ME' 'D~STR[~UT~ON" (HRS): 6eO0 - NOr 5KZD RIG 3.00 - RU~ HOO~ UP SERVICE L~NE 3.00 - OTHERt RIG UP RUN N~PEL[NE SS= CUT S~ [N .............................................. PU~ ...... a'~'OVE CRV?TV- CUT 2 D~N-*"TOH*'-N/N~aEL~N~ t,oo- ctac, PU~P 6q RELS D%L ~N 55 2.00 - OTHER ~ Wait ON PlU& PAT. WHEN C[aC TO ~ILL - DID NOT GET RETURNS FL 2300 FT FELL TO 3gOO FT [N ............................................. b'O'""M[N. CONTACT ENGiNEEriNG''''''a' ~EC~'~'~S""PEUG q.50- OTHER~ ~X ~,aeO~D 5~LT- gSL P~ 1.50 - LC~ PU~P PLUG PUMP 50 ~L ,LUGX56 DISPLRCEMENT NO PRES. S~[TCH TO ~aCKSt~e~ FL 260OFT P~PD 195DSL PETtJRNS SHOOT FLUZP LEVEL SHOWN ~ELOW 5UaF~CE NOT ~P. LE TO COIJNT FEET. WILL NOT REACH SURFACE[. 3..00..~ .......~teC4. ............... ~;rc, DSC ~~.~ ~t~..~ MGS 17595 171 M~DDLE GRNO %HO~Le P~RKER 152~ AMOCO PRODUCTION~ FLAC ~&650-~-8~ Apl ~0T]~203~le~ ~UTN rO.T~2~ AUTH COST OPERATIONS: TO 7232 ~T~ PPTD 6650~ ~ W~T ON HTGH WINDS COsTs: 'DRILY 'WELL' $G~75~ CU~ WELL 2.05 - NDe N!PaLE ON TRE~ b.O~ - NU~OPe NIPPLE UP ROP5 2.00 -'-'TST~OPi .... TEST"~OP~ - 2000 ................. 2eO0 - O?HERf PUMP ~N SHORT 5Ta~NG R~?URNS UP ANNULUS 6°8 ~BL/HIN GO~ qETUaNS ~r 289 SBL° HOL~ ?AKIN~ ELU~D AT ~PPROX ~5 FT P~R ~INUTE ~HEN FULL .............................. ~t ' ~L/~N~ .............. ~IN~5 PULL ~ND STUPID ~ACK ~ STANDS LONG STRING ............. ............ ~ ...................... FLAC 8~6650-Ot-St aPZ 537~20~R~OOt aUTH TD T22at AUTH COST S150000t a~OCO g.~. 62,5000 DPERATZONS=*'*TD*'"T2]2 FTt .... PRT'D 6650t RIG'DOgN 'DUAL COSTS: D~ILY ~ELL $38956t CU~ ~ELL ~31814 "~ CHRON TZ~E D~STaZBUTtON (HRS)t 0°50- OTHERt PUMP ?~ B~L 05L TO HOL~ 4°00 '-' ...... PTGt PULL'L5 T~ L~ ¢eVtT¥ 2.~0 - OTHE~t PT~ UP WL TaG riLL 6T 6560 ~T THIS CCVER5 ~PP~CXI~TFLY qO FT OF RT~ PERFS. UNABLE TO ~EEP FLU~ L~VEL ~OV~ 2000 FT ELECTED NOT TO .............................. aTTE~eT"ANY'CLF~N ~T' THIS T~E"'DUE-TO"L~N'"FLUID 'LEVEL- ..................... ,]ed0 - RUt ~IG UP TO RUN DUAL T~G 13.O0- RTGt PU MUEL SH~OF.1 JT TAtL P~PE,~O~,E 3" TYPE ~-OPF lH~ SN-L22'PUN IN HOL~ ON 3-1/2 ~U~L T~G HYDRO T~G DEP?~4 ~UFL SHGO~ LANDED A~ 6021 C~V:TY RT ............................................................................................................... ................... . .................................................. MGS 175q5 t7~ ~IDDLE GRND SHOALt . AMOCO PRODUCT~ONt FLAC 846650-01-8t APl FOT332038[OOe 8UTH rD 722qe aUTH COST S150000e a~OCO ~.I. 52,5000 OPERATEONS: TO 7~32 FT, P~Tg 6650, SK[DDTNG PIG, [~ ..... ~.~_[..~.~L ................. COSTS:"'Oa'ZLV CU.' LL StSn 7. ............... CHRON TIME DTSTRI~UTTON (H~S): O.SO- RSERe SLIP DRILL LINE ....................... !,90''~ ....... NDgDP~ NZPPL'E 9N ~OPS ............................................ 2.50 - NU~ ~IPPLE UP TREE aND TF'ST 2,53 - 0THCPt ~IG UP WL RUN STaNDing V~LVE STaNDiNG V~LVE T~GGE~ FLUID LEVEL AT 2290 FT ....... 1'.OO'''~ ..... C~R'Ce ........... E]RC'"TBG STRGS' W/P.O. ~ENVE~ ,~ JF.T ~U'~P SN-'I. O0~ W~T~ ?~.~ N,q?~L~ PUMP ON MG$ 17~9.~ l?t "~DDL.c ~o~~~.-~~-~~o~,....~.~ .............. .....:..o:~ ~...~..~...~........:~~~~~..~~~o~~~~ ~ . ...... FL~C"8~'6gO~C1-8t ~PZ '~0~332038~00t ~UTH TD T22~i .... A'UTH COST"$15OOOOt ~OCO W,I, 62,5000 ~PERATIONS: TD 7232 FY COSTS: CU~ UELL S15967~ 2~,00 - OTHEPe PU~P[NG NO GAUGE MG$ 17595 l?t R~IDDL£ GRND SHO~,Le 9 AMOCO PRODUCT]ION9 ..... ~L~C'"8~'6'65O~'~l-8'e"~PT' ~0733~03~10~t '~UTH TD 722~t "~UTH"COST'~I~OOOOe OPER&TIONS: TD 7232 FT COSTS~ CU~ ~ELL BPGPD 1015 a 2700 PS~ FLUID LEVEL 2q~ FT CHRON TtHE DZSTRZ~UT~ON FLAC 6~6650-C1-8~ APl 50733203~100~ AUTH TD 722ht AUTH COST $150000, COST~: CUu ~ELL ~EM~RKS: ~ ~ TEST: JET PU~P: ~L~ CLtJI~ 70.5 ~ 32.8~ WT~ ~CF 2~ HR = 115:G0~=303 - ~O/D=ll,5 ~ 3500 PSI. ......... .......... ~LU~D LEVEL"= '3b2OFT;"GTY 3~.~' 3 60 ~EB .................... CHRON TIME DISTRIBUTEON ('FIRS): 2~.00 - OTHER~ PUHP~NG NO GAUG~ ................................... ................................ MGS 17~95 17~ MIDDLE CRND SHO~L~ ~ ~MDCO P~ODUCTION. ~~~~~~~~***~-~~~~~~~~~~~~~ ~.,~-...... ................................. . .............. REStCN ~'.~ · *** '--[2/06/87-'e*~ ..... HGS 17S~5 l?t ~I~OLE G~ND SHOALt t ~HOCO PRDDUCTIONe . a~gCa W.I. 62.50C0 COSTSt CU~ WELL $15967~ ...................................................................................................................... 2~.00 - OTHER~ PU~PTNG NO G~U~E e,', ...... t2/o?/87 .... e~ .................................... ....... FL~C "8q6'650~01~8"~''' 'apl'' 507332038100' ~UTH TD' ~'22q~ .... ~UTH'"COST 1150000"~ ........................................... ~OCO ~.l, ~2.50a0 OPE~aTZONS= TO 72]2 COSTS: CU~ HELL SI~q67q ........................................... CHRON TIME 2q.O0 - OTHER, PUMPING NO GAUGE ....................................................................................................................................... *** ].2/08/8'/ MGS 17595 17, MIDDLE G~ND SHOatt , A~OCO PROOUCT~ON~ ~L~C 8q~650-01-8, ~") 50731203~[00~ BUTH TD 7~q, ~UTH COST ttSOCO0~ ~MOCO W,I. 62.50C3 DPER~TSONS: TD ~232 FT .... COSTSt"'CU~'~ELL' ~15~G~ .................................. RE~ARKS~ ~ HR TST ~LS FLUIDL 75.2; GTY 35,q~ BSW HCF 71.k FOR 2q HRS.~ GOR 261; LIFT IN ll~l a 3500 PSI CH~ON TIME D~STREBUTEON (HR$): DENVER MGS I?SQ5 17t MZDDLF GqND SHD4Lt e aPOCO PRODUCTION~ CHRDN T~ D~TR~UT~N (NR~)~ ............... 2k.O0 - OTHFP~ PUHP~NG'NO oo "'FL'~'C" 8h66DO~Ol-Se' APT"'50733203.S[OOt ~UTH"TD 722¢'~'"AUTH 'COST'~15000'O~ ........ aMOCO W.[. 62.~000 OPERATIONS: TD 723~ ~T COSTS: CU~ HELL ~lEeGTq ............ CHnO~ TT~E DTSTRIBUTTON (HR51: ~1,00- OTH~Rt PUMPING ND G~UGE MGS t?SeS 17 ~~ ~ SHO~ A.~CO ,~O~UCT~ON, ...... ~L't~'"8'~O~I~"8'i'' ~P~" SO~3]~OtS~OOt ~UTH Tg T2~"i .... ~""COST'"$1'~O000i nmOCO W.I. 62.5000 OPERATIONS: TD 7232 ~T COST~ CU~ W~CL $1~967h L[¢T ZN 11~7 ~RLG ~ 3500 CHRON T~MF D[STRIBUTION 2q. O0- ~TH~, PUMPING NO G~UGE ................................ .... FLOC 8k66EO-CI-8~ ~e! ~1203A1~0~ ~UTH TD 722~, aUTH COST ~I~OCO0~ ~MOCO Wol. OPERATIONS: 7D"72'32 ~T ...................................... CO,TS= CUM WELL RE~RKS= 2 HR TST= ~BL FLUID LIFT I~ llkS ~ ~SOC= FL ~mO0 - ~TH~Rt PUHPIN~ ~0 ~U~ ~GS 17~95 17~ ~I~DLF GRNO SHOAL° e ~OCO PRODUCTTONe FLOC 8~6~0-01~8t n~! ~'73~203~190t ~tJTH TD 722~t ~LITN CGST $1SOOO3t ~OCO W.I. 62.5.000 OPE~T!ON$= Tp 7232 FT CO~TSt CU~ W~LL CHRON TImE D~$TRZ~UT~ON (H~)t ................... 2~,~0 - ~THER~ PUHP~NG NO G~U~ ~gS ~,75~5 17~ MI~DL~ G~ND SHg,1L~ t ~MOCO mmOOl~CTt[1N~ FL~C"'8~6"6~O'OI~t ~PI""~O733203~l~Ot aUTN TO 722~t '~UTH COST $150000~ ~HOCO W.I, G2,50~0 OPERGTIONS~ TD 7232 COSTS: CUM WELL S15967~ CH~ON T'~F DISTribUTiON ~,30 - OTHER~ PUVP]NG. NO HG5 17595 17t HIDOLE GRND $140aLs t ~HOCO PRODUCTION, FLOC 3~6~0~01-~ ~PT'~OT3~2O~I~ ~tJTH T~ 77~t ~UTH C~%T t/5OOOOt 0PER~TIONS: TD 72]2 cT COSTS: CU~ g~LL CHRON TZ~E DISTa~UTION'(HR51: 2~°O0 - 0THER~ PU~PZNG NO G~UGE: CL bENVE~ AMOCO. W,I, £2,50C0 OPERATIONS: TD ?232 VT CtTSTS: CUM WC. LL $15qG?t~ CHRON'"T*iME"DirST;~I~UT1:,qN (HRS) .' " 2q. eO0 - OTHER, PUMPZNG NC: GAUGE IrL FLAC 8qE650~el"Si' AP~ 50713203alOOp AUTH TO' 72~ "AUTH COST t150000~ "' AMOCO W,~, &2.50~0 DPERAT~ONSI TO ?232 FT COSTS: CUM WELL $15qGTq .... m** .... 1~/19/87 "'**~ .......................................................................... . COSTSt CUM WELL CHRON TI~F ~ISTRIBUTTON (HAS): . MGS' ITSqS'"lT~ M1:,nJJILF.. G~N1? SHOAL,, .~POCO PRCJgUCTIBN, .............................. FLOC 8t. 66S0-C]-8, apt 507.$32038100,~ aUTH TD 7~2'~, RUTH COST AMOCO W.I, 62.5000 OPERaTiONS: TI~ T~"J,? mt .......... COSTS: CUM WELL t15967~ CHaC]N T~H~ D~$TR[P. UT~GN ~,:~0 - O~H~ DU~P~: fLUID LEVEL ~369 ~r. : .... ................... MGS 17595"1T~ MT~DL~ ~ND SH~nLt ~ ~ePC~ ~aCDUCTTON~ , · , . ... ..: FLOC 8k6GSO-C~-8~ ~P1 ~{]7~20~5~0~, ~UTH TD T22~ AIJTH COST ~IgO000~ aMOCO W.~, 62.50C0 OPERA'TZONS: TD' T232 ~T ........................... ~NVER · ,ao ..... [212218? o~ MOS 1't5 qE FLR~--'8~6650~01~'8~ aPT ~O733203BtO~t ~tITH TD 7~2~t"~'UTH COST IJSO000t a~OCO DP~RATZONSt TD 7232 FT COSTSJ CU~ ~ELL ~:oo ...... 1~/2~1a'7 .... ce.* ............. NGS :[?Sg~ t.?~ NII3DLF GqND SHtl~L~ ~ ~I~CICO PRODUCT~ON~ FLaC-'"'~GGSO~C~'~'8't' ~ ~073320~.q]O~t ~UT~ TD 727~t "aUTH COST AMOCO W, I * 62 OPERaTiONS: TD 1232 PT COSTS: CUW ~ELL 2~.00 - OTHER~ PUMPING NO NGS 175q5 ITt ~IggLF G~N~ SHO~Lt t ~uaCO ~gDt,JCTTONe .... FLKE--8'~'G650~O1;St ~P! 507332038100, ~UTH TD'"722he"~UTH'COST $150000~ ..... a~OCO W,I, S2.DOCg OPERATIONS= TO ?~32 ~T COSTS: CUM WELL s1~q$7~ ~o00 - gTHE~t PU~PZNG NO GU~Gc a~gCO W,T. gPFR~TIONS: TD 7232 CASTS: CUM WELL DALLY [~I~ILLING WlR[~ DIS?RICT DALLY WIRE )ENVE~t aF. GIU.q ~-.~: ANCHClaAGE DlStr~lct :::~ OI/Oe~/RFI ~C~ PAGE. OI COMPANY OPERATED htECOMPLETIDN - DEVELOPMENT FLAC ~65650-01-~e APl 50733203~1100~ ALITH TD 722e FT~ AUTH tVb ~qO0 Fre AUTH COST $1500001 AMgCO We I . 62.5000 GRAVITY 5~e~; G~ ~55; llPDPD flab l]i~L · 3500 PS1; FLUID LEVEL ~365 FT FROM SURFACE CURRENT 'dELL ACTIVI TY-COMPLT-O~Gt DATE ~ND OF JOB SUMMARY: OP[f~ COUPLETED DATE 11/30/~7 F I NAL END OF REP~.IRT CONFIDENTIAL A G y r o d a t a D i r e o t i o r, a 1 f ,-~ r C 0 P R.D...OW~-T-t-QN--4~47-m.tP_LRJ~ Y ./'~GS !7595 WEL. L MIDDLE GROUND SHOA'E ~... Date Rur,: 17-DEC-85 14:20:0 ..~, ~. -~ ~ Job Number: CAl,:8ob~ 15 Surveyc, r: PAUL J. D'AMICO Calculatior, Method: RRDIUS OF CURVATURE Proposed Well Directior,: N 1Gdeg 3Omir, Osec E Vertical Seobior, Calculated f~.'om Well Head L. ocatior, Closure Calculated fro~,~ Well Head Location Horizontal Coordir, ates Calculated from Local Horizor, tal Referer, ce S u r v e y JUL 3 0 1986 Alaska 0il & Gas Cons, commission Anoho,mge CERTIFIED SURVEY AMOCO PRODUCTION COMPANY MGS 17595 WELL ~17 MIDDLE GROUND.,.SHOAL MEAS DEPTH ft 0.8 100.0 200.0 300, 0 400.0 500. 600,0 '~700. 800. 900. 1000, 0 1100.0 1200.0 ~1300.0 -I 400, 0 1500. 1600. 1700, -1800. 1900, 2000. 2i00. -2200. ~ 0. 2400. INCL deg n~in 0 17 0 25 :, 9 ! 17 I 8 1 ! 1 4 i 7 1 8 1 8 1 6 1 12 2 42 5 20 8 57 11 42 13 12 14 51 16 33 18 3'7 19 7 !8 42 18 35 BORE HOLE B2ARZNG de~ N 0 0 E N ~525E S 35 20 E N 25 45 E N 3'7 40 E N55 ISE N 54 33 E N 50 !7 E Ixl 47 36 E N 53 49 E N 54 9 E NS1 25E N 54 4 .'t. E N28 4 E N 21 0 E N 23 2,2 E N i647E N 10 36 E N 5 55 E N 5 40 E N 6 18E N 8 1 E N 4 48 E N 0 i5W N 0 52 W V E R T DEPTH ft 100.0 200.0 300, 0 400.0 500.0 599.9 699.9 799.9 899.9 999.9 1099.8 1199.8 1299.8 1399.7 1499.5 1598,7 1697.1 1'794.7 1891.7 1988.0 2083,3 2177.9 2272.5 236'7,3 CONFIDENTIAL VERT C L 0 S U R E SECT!ON DISTANCE BEgR!NG f t f t o e ~ ~"~ i r~ 0.0 ,2 .5 .7 2.0 3.9 5.5 7.! 8.6 10.2 1!.7 i3.3 14.9 i6,7 20.1 2'7. 1 39.5 57.4 78.7 ! 02.5 129,1 !58.9 190.8 222.2 252.7 H O R i Z O N T A L COD RD .feet Page t DOG-LEG S~VERtTY deg/100' 14. ,S N 5 i 25 E 16,3 N 5:[ 35 E :[8.3 N 5! 44 E 20.2 N 5~Z~ 44 E 23.3 N 47 2 E 3.0 N 3.5 E ' 42N =3'E 5.4 N 6.8 ~': 6.6 N 8.! E '7.8 N 9.6 E 8.9 N 11.2 E 10, 1 N 12, 8 E 11.3 N 14,3 E 12.8 N !5.6 E 15.9 N 17.1 E 22.4 N !9.7 E 34. i N 24.0 E 5!.5 N 28,2 E 72.8 !'~ 31,3 E ~o. 9 N J,.t,,.8E :L23.8 N 36.6 E i53.8 N 40.4 E !85.9 N 44.0 E 218.3 N 45.3 E 250.3 N 45.0 E 2.9.8 N ~1 23 ~ 41.'7 N 35 !i E 58.7 N 28 4.5 E 79.3 N 23 18 E 1~.,c.6 N 19 13 :' 129,1 N 16 28 E 159.0 N !.4 42 E 19i.! N 13 19 E 222.9 N ii 43 E 254.3 N !0 !! - · 39 .t5 .t4 .06 .13 . .03 .05 .07 .54 1.53 2, 64 3.70 2.97 1.79 1, F7 ) 2.13 i. i6 1.69 · 22 AMOCO PRODUCTION COMPANY MGS 17595 WELL ~1:17 MIDDLE GROUND.,SHOAL CONFIBEN I L Pa ge 2 MEAS DIF_'PT'H ft 2500.0 2600.0 2700.0 2800.0 2900.0 3000.0 3100.0 3200.0 3300, 0 3400.0 3500. 3600. 3700. 3800. 3900, 4000.0 4!00.0 4200, 0 4300.0 4400.0 4500, 4600, 4700. 4800. 4900. INCL d e_u '] i r~ 18, 3 i 7 ,45 17 53 t8 56 20 2 21 2 22 11 2.3 8 22 25 22 0 21 37 2! 9 21 40 22 53 23 4.9 24 4-8 25 54 26 59 27 35 28 2 ~6 46 25 34 24 59 24 ~ BORE HOLE BEARING Oeo N 0 14 W N '0 9 W 19 0 25 E N 052E N 1 3 E N i 33 E N 2 11 E N 2 17 E N 3 15 E N 4 15E N 4 4.2 E N 4~ ~ N 5 48 E N 6 47 E N 8 0 E N 938E N i046E N 1I 21E N 12 15 E N !248E N 12 34 E N 12 8E N 540E N 720E N 9 OE VERT DEPTH ft 2462.2 2557.4 2652.6 2747.5 2841.7 2935,4 3028,3 3120.6 32!2,8 3398.1 3490,9 3584.1 3677.2 3769.7 386!.5 3952,6 4043.0 4132.5 4221.4 4309.9 4398.7 4488.4 4578.8 4669.6 VERT C L 0 S U R E S,ECT' I ON D I STANCE BSA R l r,.!G ft 'ft deLj rain 282.8 3!2.2 341.6 371.9 404.1 437, 9 473.6 5!0.9 548.5 585.4 622.1 658.4 694,2 730.1 767.5 806.8 847.7 890.3 934.7 980.4 1027.0 1072.9 1!16.6 1158. G 1200,! 285.2 N '9 0 E 315.6 N 8 7 E 345.9 l',.t7 25 E 377.3 N 6 51 E 410.5 N fS 22 E 445.4 N 5 58 E 482.2 N 5 39 E 520.6 N 5 24 E 559.3 N 5 ].3 E 597. 1 N 5 8 E 634.6 1'4 5 5 E 671.8 N 5 4 E 708.2 N 5 4 E 744,. 7 N 5 8 E 782·6 N 5 14 E 822.2 N 5 25 E 863.2 N 5 38 E 905.8 1'4 ',5 =z ,...~ + E 9~,0. i N 6 !0 E 995.7 N 6 28 E !042.1 N 6 44 E 1087,9 N 6 59 E 1131.9 N 7 3 E i174,6 N 7 2 E 1216.5 N '7 4 E H 0 R ~ Z [] C DO R D feet 281.'7 N 44.7 E ,312.4 N 44.6 E j';43.0 N .44.6 E 374.6 N 45.0 E 407,9 N 45.5 E 443.0 N 46.3 E ' 4'79.8 N 4'7.5 E 5!8.3 N 49.0 E ,...,~,'. 0 I'4 50.9 E 594.8 N 53.4 E 632.1 N 56.3 E 669.2 N 59.3 E 705.5 N 62.6 E 741.7 N 66.6 E '779.3 N '71.4 E 8i8.5 N 859.0 N 9~i.0 N 944.6 N 77.5 E 84.8 E 93.0 E 102.1 E 112.1 E ~.-_';'-'. ,5 c !32,1 E 139.0 E 143.8 E 149.7 E !034.9 N 1079.8 N 1123.4 N I!65.8 N . c_~,7, e., N DOG-LEG SEVERITY deg/i00' .5'7 .2E 1.06 1. I1 1.02 1. 1'7 .96 .82 · 53 .18 ,40 .67 ,63 1.3i 1.13 1.08 !.13 1.15 1.28 3.09 ,92 · 82 AMOCO PRODUCTION COMPANY MGS 17595 WELL ,W, 17 M I DDLE GROUND...SHOAL CONFIDENTIAL MEAS I NCL BORF HOLE DEPTH BEAR I NG ft de@ rain de!~ rain 5080.8~ . 20 43 N 16 33 E 5100.0 17 9 N 89 18 E 5200.0 15 9 N 39 49 E 5300.0 14 53 N 4.1 24 E 5480.0 14 44 N 41 11 E 5500.0 14 50 N 42 32 E 5600.0 t4 42 N 43 39 E 5700.0 15 ,6 N 4.4 17 E 5800.0 15 14 N 45 1 E 5900.0 15 35 N 44 9 E 6000.0 15 41 N 44 26 E 6100.0 t5 7 N 45 2I E 6200.0 i4 54 N 45 !8 E 6300.0 14 52 N 45 24 E 6400.0 14 4 N 46 57 E 6500.0 13 58 N 47 3 E 6600.0 13 35 N 47 8 E 6700.0 13 23 N 47 12 E 6800.0 t3 4 N 48 1 E 6900.0 !2 34 N 47 49 E 7000.0 11 53 N 47 33 E 7100.0 11 52 N 47 37 E 7160.0 ii 36 N 47 33 E 7200.0 I1 36 N 47 28 E 7232.0 11 36 N 47 31 E VERT VERT DEPTH SECT t ON ft ft CLOSURE D!STANCE B!EARING f t d e o m i n 4761.9 1238.4 4856.5 1270.6 4952.5 1297.0 5049. I 1320.7 5145.8 1343.9 1254.8 N 7 15 E i286.0 N '7 38 E !310.8 N 8 11 1332.7 N 8 47 E 1354.4 N 9 22 5242.5 1366.9 5339.2 1389.'7 5435.8 1412.6 5532.3 1435.6 5628.7 1459.0 l i~76.0 N 9 56 E 1397.4 N 10 30 E 1418.9 Rt 11 5 E 1440.8 N !i 39 E 1463. 1 N 12 13 E 5725.1 1482.9 5821.5 1506.2 5918.0 1528.9 6014.7 155!.4 6111.5 1573.1 1486.0 N 12 46 E 1508.6 N 13 18 E 1530.6 N 13 49 E ~,~.5 N 14 19 E 1573.8 N 14 48 E 6208.6 1594.0 6305.7 16t4.5 6402.9 1634.5 6500.3 !654.! 6597.8 1673.1 1594.~4 N 15 16 E i614.6 N !5 42 E 1634.6 N 16 8 E 1654.1 N ].6 33 E 1673. t N !6 56 E 6695.5 1691.2 1691.4 N 17 I8 ~ 6793.4 !708.8 1709.2 N i7 39 E 6852.1 17i9.3 17!9.8 N 17 5~ = LAST TWO DEPTHS PROJECTED TO TOTAL DEPTR 689i.3 1726.2 1726.8 N 17 59 E 6922.7 1731.7 !732.4 N 18 6 E H 0 R I Z 0 N T A L. COO RD .feet 124,4.7' N t58.2 E !274.6 N 170.8 E 1297.4. N 18~.6 E i317'.I N 2~3.5 E !336.3 N 220.3 E 1355.,3 N 237.4 E ' 1374.0 N 254.8 E !~92.5 N 272.6 E I41t. 1 N 291.0 E 1430.0 N 309.7 E 144.9.3 N 328.5 E 1468. i N 347.2 E 1486.3 N 365.6 E !504.3 N 383.9 E 1521.6 N 401.9 E 1538.]. N 419.6 E i554.4 N 437.1E 1570.2 N 454.2 E 1585.6 N 471.1E t600.5 N 487.5 E 1614.8 N 5'~3.2 E 1628.7 N 518.4 E 1636,9 N 527.4 E 16421.3 N 533.TM~ = ~ 1646.7 N 538.1 E DOG-LEG SEVER1TY deg/100, , 5.4 ) 3.5~ .49 .16 .36 .31 .42 .24 .42 .!3 .61 .22 .05 .88 .11 .37 .20 .37 ' .44 .04 .04 Final ~ * C1 ~ '~'-' .,., ~a~ion c:sure: ~7~:,-.4 feet Nnrt~ 18 deo_ 5 m'~'.''' 44 sec East Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · OPERATOR, AND NUMBEK Reports and Materials to be received by: ~- ~/- Date · , - Required Date Received Remarks Completion Report Well History /~//C~ ..~'~ /?-~'~ ~/~ Samples ~ -hi ....... ~ ~ /~ ,, Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey ~. ~~(~/~,. ~e~t~on~ Survey ~-~/t~ 'Drill Stem Test Repogts _ ~od~et~o~ ~eet ~epo~te W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage. Alaska 99510 907-272-8471 April 11, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: FEW-O99-WF Gentlemen- Monthly Report of Operations Granite Point 18742 Well No. 36, Platform Anna, and Middle Ground Shoal 17595 Well No. 17 Platform Baker, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced wells reporting March, 1986 activities. . Very trulY ~yours ~' W. G. Smith District Manager Attachment KWU/jr RECEIVED fZ 1 5 1986 Alaska 0il & Gas Cons. Commission Anchorage .,~-~... STATE OF ALASKA ~ . . ALASKA . AND GAS CONSERVATION C 711SSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS.,, · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No· Amoco Production Company 85-217 3. Address 8. APl Number P. O. Box 100779, Anchorage, Alaska 99510 5o- 733-20382 4. Location of Well at surface Leg 4, Slot 7, Platform Baker 1,982' FNL, 481' FWL, Sec. 31, TgN, R12W, S.M. 9. Unit or Lease Name MGS 17595 10. Well No. 17 11. Field and Pool Middle Ground Shoal Middle Kenai Sands March 86 For the Month of. , 19~ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at end of month - 7,232 feet 13. Casing or liner run and quantities of cement, results of pressur9 tests None 14. Coring resume and brief description None 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data See atatched chronological history. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED v .,~ _ _ · TLE DATE 04/11/86 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate MIDDLE GROUND SHOAL 17595 NO. 17 CHRONOLOGICAL HISTORY 3-1-86 to 3-31-86 Pump test BC sands. Average March production' 574 BOPD x 120 BWPD x 279 MCFD. W. G. Smith District Manager Amoco Production Company Post office Box 100779 Anchorage, Alaska 99510 907-272-8471 March 13, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: FEW-O69-WF Gentlemen: Monthly Report of Operations Granite Point 18742 Well No. 36, Platform Anna, and Middle Ground Shoal 17595 Well No. 17 Platform Baker, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced wells reporting February 1986 activities. Very truly yours, W. G. Smith District Manager Attachment KWU/dds RECEIVED "' - : ' ' " C':;~nm/ssion 2, · ~ '~ .----~. STATE OF ALASKA ----~ ALASKA,,_ .AND GAS CONSERVATION CC AISSION ' MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Amoco Production Company 85-217 3. Address 8. APl Number P. 0. Box 100779, Anchorage, Alaska 99510 50- 733-20382 9. Unit or Lease Name HGS 17595 4. Location of Well at surface Leg 4, S]ot 7, P]atform Baker 1,982' FNL, 481' FNL, Sec. 31, T9N, R12W, S.M. 5. Elevation in feet (ir~a.t~r ~B~I:, etc.} I 6. Lease DA~L~at~p~i~Ser'al No. 10. Well No. 17 11. Field and Pool Middle Ground Shoal Middle Kenai Sands For the Month of. Feb ru a ry 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at end of month - 7232 feet 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None RECEIVED 6. DST data, perforating data, shows of H2S, miscellaneous data See Attached chronological history. MAR 1 8 1986 Alaska 0il & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoi,~g is true and correct to the best of my knowledge. SIGNED TITLE DATE 03/13/86 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 Submit in duplicate 2-1-86 to 2-28-86 Pump test BC Sands. Six hour test 02-14-86. 512 BOPD x 64 BWPD x 216 MCFD. ~'JAR 1 8 1986 '. ~; ~.;u.",,s;. Commission , W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 9O7-272-8471 February 18, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: FEW-O49-~F Gentlemen' · Monthly Report of Operations Granite Point 18742 Well No. 36, Platform Anna, and Middle Ground Shoal 17595 Well No. 17 Platform Baker, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced wells reporting January 1986 activities. Very truly yours, W. G. Smith Di strict Manager Attachment KWU/dds RECEIVED F E B 2 4 1986 l~i ~;J'r'~r,l.. .:id STATE OF ALASKA ALASKA ..AND GAS CONSERVATION C~ ,MISSION MONTHLY REPGRT OF DRILLING AND WORi(OVER OPERATIONS · Drilling well ',~ Workover operation 2. Name of operator Amoco Production Company 3. Address P. O. Box 100779, Anchorage, Alaska 99510 4. Location of Well at surface Leg 4, Slot 7, 1,982' FNL, 481' R12W, S.M. 5. Elevation in feet {indicate KB, DF, etc.) 79.4' KB Platform Baker FWL; Sec. 31, T9N, 6. Lease Designation and Serial No. ADL 17595 For the Month of ~ .... ua,,ua~-y I~6 7. Permit No. 85-217 8. APl Number so- 733-20381 9. Unit or Lease Name MGS 17595 10. Well No. 17 11. Field and Pool Hiddle Ground Shoal Middle Kenai Sands 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at end of month - 7,232' TD 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None' 15. Logs run and depth where run None RECEIVED 6. DST data, perforating data, shows of H2S, miscellaneous data See Attached-chronolOgical history. 17. I hereby certsfv that the foregoing is true and correct to the best of my knowledge. District Manager SIGNED__ ITLE DATE 02/18/86 ' NOTE--Report on this form is required for each calendar month, regardless of the-status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeed-ing month, unless otherwise directed. Form 10-404 i . Submit in duplicate . MIDDLE GROUND SHOAL 17595 Well No. 17 PLATFORM BAKER 01-01-86 to 01-05-86 01-05-86 to 01-10-86 01-11-86 01-12-86 01-13-86 to 01-31-86 F1 ow testing well. Attempt to kill well with emulsified diesel. Could not kill well with 8.8 ppg fluid. Kill well with 9.4 ppg brine. Run dual 3½-inch tubing and Kobe 3-inch cavity. Release rig at 0600 hours. Seat pump. Pump test well. Four hour test 01-30-86 732 BOPD x 126 BWPD x 266 MCFD. RECEIVED ~,t~s!.',r~ Oil ~:', ?' ~; (;?"~ C. ......... STATE OF ALASKA ~-. ALASKA ~ AND GAS CONSERVATION CC .~IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Amoco Production Company 85-217 3. Address 8. APl Number P. O. Box 100779, Anchorage, Alaska 99510 50- 733-20381 4. Location of Well 9. Unit or Lease Name MGS 17595 at surface Leg 4, Slot 7, PlatfOrm Baker 1,982' FNL, 481' FWL, Sec. 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 79.4' KB ADL 17595 10. Well No. 17 11. Field and Pool Middle Ground Shoal Hiddle Kenai Sands For the Month of. December ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at end of month 7,232' TD Footage Drilled - 2,798' 13. Casing or liner run and quantities of cement, results of pressure tests 9 5/8-inch casing set at 7,232 feet. Cemented first stage with 1,100 sx Class "G". Cemented second stage through "DV" tool at 4,385' with 1,000 sx Class "G". Drilled out to 7,180' PBTD and tested casing to 1,750 psi for 30 minutes - OK. 14. Coring resume and brief description None 15. Logs run and depth where run DIL, SP, Caliper, GR CNL, CDL, GR 7,230 - 3,230 7,230 - 3,230 RECEIVED 16. DST data, perforating data, shows of H2S, miscellaneous data See Attached chronological history. Alaska 17. I hereby certify that the foreg,,oi~g is trjj~and correct to the best of my knowledge. SIGNED LE DATE 01/17/86 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate MIDDLE GROUND SHOAL 17595 WELL No. 17, PLATFORM BAKER 12-01-85 to 12-03-85 12-03-85 to 12-05-85 12-05-85 to 12-14-85 12-15-85 12-16-85 12-17-85 12-18-85 to 12-19-85 12-20-85 12-21-85 12-22-85 12-23-85 to 12-35-85 Drilling 4,434 - 4,897 feet Mud motor 4,897 - 5,189 feet Drill 5,189 - 7,232 feet Logging DIL, SP, CAL, GR CNL, CDL, GR 7,230 - 3,230 feet 7,230 - 3,230 feet Run 9 5/8-inch casing and cement first stage with 1,100 sxs Class 'G'. Cement second stage through "DV" tool at 4,385 feet with 1,000 sxs Class 'G'. Drill out DV tool and clean out to 7,180 feet PBTD. Pressure test casing to 1,750 psi for 30 minutes - OK. Run DST on "D" sand. Perforate 6,663 - 6,683 feet, 6,700 - 6,727 feet, 6,788-6,800-~-T--. Open five minutes, SI 30 min, Open 90 min, SI 3.5 hrs, 8 barrels influx. Reversed out 9~9 pe~r with trace of oil. Set CIBP at 6,650 feet MD. Perforate "B" and "C" sands 6,022-6,052 feet, 6,104-6,130 feet, 6,162-6,220 feet, 6,385-6,430 feet, 6,455-6,472 feet, 6,483-6,500 feet, 6,519-6,562 feet, 6,587-6,600 feet, at 4 SPF. Flowing well through drillpipe. Packer set at 5,980 feet - testing. Flowing and testing well. Flow test on 12-30-85; 660 BOPD, 96 BWPD, 282 MCFD. [ ECEIVED Alaska Oil & Gas Cons. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Receipt of the fOllowing material which was transmitted via is hereby acknowledged: .QUANTITY DESCRIPTION RECEIVED: _~~ ~ DATE~ ~~~/~ ~ Copy s~~ sender YES NO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE: Receipt of the following material which was transmitted via is hereby acknowledged: QUANTITY DESCRIPTION RECEIVED: ~-/~ ~ / ~~ DATE ~ Copy YES sent to sender N0 W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage. Alaska 99510 907-272-8471 December 16, 1985 Mr. 'C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: FEW-O34-WF Gentlemen' Monthly Report of Operations Granite Point 18742 Well No. 35, Platform Anna, and Middle Ground Shoal 17595 Well No. 17 Platform Baker, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced wells reporting November 1985 activities. Very truly yours, W. G. Smith Di stri ct Manager Attachment KLS/dds :~ ' ~" "~' STATE OF ALASKA ALASKA L,.~. AND GAS CONSERVATION CO~JVIISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. Amoco Production Company 85-217 3. Address p. 0 Box 100779, Anchorage, Alaska 99510 8'APINun~-20381 · 50- 9. Unit or Lease Name MGS 17595 4. Location of Well atsurfaceLeg 4, Slot 7, 1,982' FNL, 481' R12W, S.M. Platform Baker FWL, Sec. 31, T9N, 5. Elevation in feet (indicate KB,DF, etc.)I 6. Lease DesignationandSerial No. 79.4'KBI ADL 17595 10. Well No. 17 11. Field and Pool Middle Ground Shoal Middle Kenai Sands For the Month of Nnvemher , 19_R~ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud Date 11-12-85 Depth at end of month - 4,434 feet Footage drilled - 4,434 feet 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20-inch set at 630 feet with 838 sx lead and 500 sx tail Class "G" 13 3/8-inch set at 3,237 feet with 2,200 sxs lead and 500 sx tail and pressure test to 1,500 psi for 30 minutes. Cl ass 14. Coring resume and brief description None 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED I :!985 Anchora~o 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED _ .-~ E DATE 12/16/85 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duolicate Middle Ground Shoal 17595 Well No. 17, Platform Baker 11-12-85 to 11-14-85 11-14-85 11-15-85 11-16-85 to 11-18-85 11-18-85 to 11-21-85 11-22-85 11-23-85 11-24-85 to 11-25-85 11-26-85 to 11-27-85 11-28-85 to 11-30-85 Spud well and clean out 30-inch slot mud motor to 448 feet (17½-inch hole). Drill to 630 feet and open hole to 26 inches. Run 20-inch casing to 630 feet and cement with 838 sx 12.6 ppg lead slurry and 500 sx 15.8 ppg tail surry. Nipple up lO-inch diverter system and drill to 1,270 feet Kick-off with mud motor 1,270 - 1,768 feet Drill 1,768 - 2,184 feet Mud motor 2,184 - 2,296 feet Drill 2,296 - 3,240 feet Run 13 3/8" casing to 3,237 feet and cement with 2,200 sxs lead slurry and 500 sx tail slurry. Test casing to 1,500 psi. Run formation integrity test to 13.5 ppg EMW and drill to 4,434 feet. RECEIVED A!aska Oil & Gas Cons. Commission THRU: Lonnie C. Smith Commi s s loner .... ~ROM~ Bobby D. Foster~-~z' Petroleum Inspector MEMORANOUM Stat6 of Alaska ALASKA~Q,IL Ai-~ GAS CONSERVATION CO~ISSION TO: C' V. re. ton ~A~: December 2. 1985 Chai~~ .~,~ .. ~tE NO: D.BDF. 123 TELEPHONE NO: SUBJECT: BOPE Test Amoco - M.G.S. 17595 #17 Permit #85-217 M.G.S. Field ?uesdav, November 26, 1985: The BOPE test began at 2:00 PM and was g0ncl~u~de-d at~~-0 PM. ' As-~he attached BOPE test report shows, there were no failures. in summary, I witnessed the BOPE test at Amoco's M.G.S. 17595 #17. Attachment O&G tt4 5Ag4 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date Location: Sec 3 / ~__~~M ~ 13~C, asing SetUp@ ~, ft. Drillin~ Contractor.~~~'~ Rig (,b~~~ntative . . _ Location, General..~~ Well Sign ~' ACC~ATOR SYST~ General Housekeeping~Ri~~~Full Charge Pressure ~~ psiR Rese~e Pit ~/~ Pressure After Closure 7~ ~ psi~ Mud Systems Audio Visual Trip Tank / Pit Gauge / Flow Monitor / Gas Detectors Representative ~ ~~~~ Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: Test Pressure BOPE Stack Annular Preventer Pipe Rams Blind Rams mi..~/Z~ gec. psig Controls: Master ~ ~ · Remote?~5 Blinds switch cover Test Pressure Test Pressure Test Pressure Test Pressure Kelly and Floor Safety Valves Upper Kelly Lower Kelly Ball Type / Inside BOP / Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Failures gP Repair or Replacement of failed equipment to be made within Choke Manifold ~e ~ Test Pressure ~--~-~ No. Valves ~ No. flanges _~ ~ / / Hydrauically operated choke / Test Time / ~.~ hrs. days and Inspector/ Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor September 18, 1985 W. G. Smith District Manager Amoco Production Company P. O. Box 100779 A~chorage, Alaska 99510-0779 Middle Ground Shoal No. 17 Amoco Production Company Permit No. 85-217 Sur. Loc. 1982-'FNL, 481'FWL, Sec. 31, T9N, R121.7, SM. Btmhole Loc. 324'FNL, 976'FWL, Sec. 31, T9N, R12W, SM. Dear Mr. Smith: Enclosed is the aPproved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to 'commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamoreau~x W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 August 29, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: TJZ-310-WF Dear Sir- Application for Permit to Drill Middle Ground Shoal 17595 Well No. 17 Platform Baker, Cook Inlet, Alaska Attached in triplicate is a State of Alaska, Form 10-401, Application for Permit to Drill for Middle Ground Shoal 17595 Well No. 17. We propose to directionally drill this well from Middle Ground Shoal Platform Baker, utilizing Leg 4, Slot 7, to a target location at the top of the Middle Kenai B sand - 5,641 feet subsea, 500 feet FNL, 800 feet FWL, Section 31, T9N, R12W, Seward Meridian. This well is to be completed as a producing Well to recover reserves from the crest of the structure north of the platform. Also attached is our company Draft No. 310964 dated August 28, 1985, for $100.00 to cover the filing fee. Two plats showing the location of the well in relation to the Middle Ground Shoal structure and a Platform Baker survey plat are attached, along with sketches of the BOP equipment to be used. Our computer program, "DEVPLAN," is included which calculates the horizontal distance between the proposed wellpath and offset Well Nos.-5, 10, 14, 18, and 25. A leg diagram and spider map shows our proposed plan in relation to the surrounding wells. A schematic diagram of the mud pits is attached, listing the equipment to be used. This will be the second well completed in the northwest quarter of Section 31, as per the provisions of Conservation Order No. 44 (dated September 19, 1967) of the Alaska Oil and Gas Conservation Commission. The other well completed in this quarter section is: MGS 17595 Wel3 No. 6 R~¢FIVED Alaska Oil & Gas Cons. Cornmissior~ Anchorage C. V. Chatterton, Chairman TJZ-310-WF August 29, 1985 Page 2 Drilling of the subject well is estimated to start on September 14, 1985. Please contact Kevin Smith or Jeff Blag§ in our Anchorage office if you have any questions concerning this application. Very truly yours, W. G. Smith Di strict Manager Attachments KLS/dds RECEIVED S~i? 0 ~ 19~5 Alaska Oil & Gas Cons. Co~-nmission Anch,.:zaOe STATE OF ALASKA ALASKA L_._ AND GAS CONSERVATION CO .... vllSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Amoco Production Company 3. Address -P. 0. Box 100779, Anchorage, Alaska 99510 4. Location of well at surface Leg 4, slot 7, MGS Platform Baker 1982'FNL 481' FWL' section 31, T9N, R12W, S.M. At top of proposed producing i,terva~ "B" Sand @ 5720' TVD, 500' FNL, 800' FWL, section 31, T9N, R12W, S.M. At total depth 324'FNL, 976' FWL, section 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. 79.4' KB ADL 17595 12. Bond information (see 20 AAC 25.025) Type Blanket Suretyand/ornumber Surety-599481 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 20 miles NW of Kenai, AKm,les 4780' FSL of ADL 17595 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease I 7224' MD, 6900'TVD feet 5106 ' i 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures KICK OFF POINT1200 feet. MAXIMUM HOLE ANGLE 26 o (see 20 AAC 25.035 (c) (2) !21 9. Unit or lease name Middle Ground Shoal 10, Well number 17 11. Field and pool Middle Ground Shoal Field Lower Kenai Conglomerate Amount 500,000 15. Distance to nearest drilling or completed 25RDwe, is 666' -S38°W(Btop)feet 18. Approximate spud date September 14', 1985 i?U/ psig@ [J surface 3189 psig@ 572Ot. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole Casing - 30" 26" 120" 17½" 113 3/8" 12¼"19 5/8" CASING AND LINER Grade_ Coupling_ K-55 ButtI K-55 ButtJ N-80 I ButtI Weight 320# 94# '68# ¢7,5~# 22. Describe proposecl program: Length 600' 3200' 7224' SETTING DEPTH MD TOP TVD 0 ~ 0 0 , 0 0 ~ 0 MD BOTTOM TVD 266' 266' 600' 600' 3200' 3122' 7224' 16900' I QUANTITY OFCEMENT (include stage data) Driven Class "G" to Surface Class "G" to Surface Cover A sand plus 501 Amoco proposes to directionally drill well #17 from Leg 4, Slot 7, Middle GroundShoal Platform Baker, to a middle Kenai "B" sand target ato5641'ss, 500'FNL, 800' FWL, sec 31, T9N, R12W, S.M. Total depth is estimated to be at'7224' MD, 6900' TVD after adequate penetration of the 'E' sand. After log evaluations, zones of interest will be perforated, and the well placed on hydraulic lift. There are no affected operators. A location plat and BOPE sketches are attached. Note: casing design factors of 1.125, 1.0 and 1.8 will be used for collapse, burst & tensile strengths respectively. Estimated maxim mud weight is /0.7 ppg. S EP 0 19B5 23. I hereby certify that the foregoing i,~true and correct to the best of my knowledge ~/.~.~,~ Alaska 0il&Gas Cons. CommiSsion SIGNED TITLE District Manaa~_~Anch°rage DATE ~--~.,~-~J5 The space below for Commission use " CONDITIONS OF APPROVAL Samples required []YES ,~0 Permit number APPROVEDBY Mud log required F-lYES ~10 Approval date _ _.--. 0911~ / 83 Directional Survey required I APl number ~YES [:]NO I 50- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE ~,~-,~m~,~ !8 1 OR5 by order of the Commission Form 10401 / Submit in triplicate Rev. 7-1-80 24 25 36 i 9~ N~ i ! ! ! ! ! I ! I ! ! ! MIDDLE ~-~602 -6898 NO. 17*'(~> ' -.~725 Baker I I I ! i I BCD Proposall · BCD Producer & BCD. Injector I · *~ BCD Abandon! .~' Non BCD .R12W , ,'1 B STRUCTURE ~ I Figure 13 GROUND SHOAL B STRUCTURE EIVED FIELD' Alaska Oil & Gas Cons. Commission Anchorage 4415. ' 4515. ' '~>~,:~:':":. ' -'"i".:': ~:':'ii i 461.5. -.,iiiii. i .'j; ]: 47i5. - "'" i'-: 47,o. : :"-- A~aSka Oil &-Oas ConS. O0mmissi~eo. - ' ' ~0, 100.00 200.00 300.00 400.00 500. O0 600.00 700.00 800.00 900,00 1000.00 1100.00 1200.00 1282.00 1382.00 14~.00 1582.00 1682.00 1782.00 18~2.00 19~2.00 20~2.~'o~.~ ~ ~ ~, O0 ~'~ O0 ~o~ O0 ~. 2482.00 ~'~ O0 2682.00 27~2.00 2882.00 2~62.00 3015.00 3115.00 3215.00 3315.00 3415.00 35!5.00 3~!5.00 3715.00 3915100 4015.00 42i5.00 FiLENAME: WELL17 TRADITIONAL ~jNITS RADIUS OF CURVATURE METHOD VERTICAL SECTION OR CLOSURE DIRECTION IS MEAS. SURVEY DEPTH NORTH EAST DEPTH INCL. DIR. (TVD) -SOUTH -WEST O0 oo O0 O0 O0 O0 oo oo oo oo oo O0 oo O0 oo oO 0.00 0.00 o. oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1,50 3.00 4.50 6.00 7. 50 9.00 10. 50 12.00 13. 50 15.00 16.50 18.00 19. 50 21.00 22.50 24.00 25.50 25,,99 25.99 ~5.99 25.99 -25.99 25.99 25.99 25.99 25.99 25.99 25.99 25.9~ 25.99 25. 99 25. 99 25. 99 24,49 21,49 19.99 18.49 16.99 15.49 13.99 1~.49 12.00 12.00 N O. OOE N O. OOE N O, OOE N O. OOE N O. OOE N 0. OOE N 0. OOE N O. OOE N O. OOE N O. 00E N O. OOE N O. 00E N 1.09E N I."1~ N 1.16E N I. ~SE N 1.38E N I.~4E N 1.73E N I.~E N ~ N 2.~6E N 3.~3E N 3. 64E N 4. 0SE N 4. 5~E N 5. 0SE N 5. 59E N 6.16E N 6. 36E N 6.95E N 7.55E N 8.15E N 8. 74E N 9. 34E N 9.9~E NlO. 54E NII. 13E Nil. 73E N12.33E N12.~3E NI3.52E N14.12E NI4.72E NIS. BIE N15.~IE N16.5iE N16.96E N17.54E N18. OgE N18.60E N19.09E NI9.54E Nig. 9.SE N20.33E N20.6~E N20.99E N23.09E N35.00E 100.00 200.00 300.00 400.00 '500.00 600.00 700.00 800.00 900.00 I~'0n O0 ll00. O0 1200.00 !~2.00 13~1.99 1581.~9 1681.27 1780. 57 1~79 .53 1978 09 2076 16 2!73 69 2270 61 2366 86 24~.36 2.-3',.05 2630.86 2743.74 2B35.62 2936.43 2956.15 30~6.04 3135.93 3225,81 ~ 70 3405. 59 3495.48 35~5.36 3765.14 3~55.02 39~4.91 4034.80 4124.68 4304.46 4394.34 4184.23 ~551.64 46~2.09 4733.63 4~26.18 4919.70 501~_11 ~I09.35 ~Z0~.35 53P9. 39 5432.61 5530.43 -1982.00 -1982,00 -19~2.00 -1982.00 -1982.00 -1982.00 -1982,00 -1~8~ ~,~, -1982.00 -1982.00 -19~2.00 -1982.00 -i~7~.7;' -1970.23 -i961.0~ -194~.33 -1734.~ -19i8.0~ -1851.?~ -!795.2~ -1763.~5 -17~.~¢ -16~1.7~ -1652.¢~ -!~!0.77 -1576..52 -1553.00 -1466.1~ -1422.77 -137~.4~ -!33~.27 -1~07.1~ -1164.3~ -il~l.5& -1078.90 -1036~3~ -951. 5~ -909.37 -867.30 -835.8~ -795.10 -755. Z7 -720.8~ -~87.3~ -bO1.3i -577.¢~ -55~.07 -549.3~ -531.24 1985-08-29 12.15 DEOREES VERT. SECTION 481.00 -1836.36 481.00 -;836.36 481.00 -1836.36 481.00' -1836.36 481.00 -1836.36 46!.00 -1836.36 481.00 -1836.36 4~1.00 -1836.36 4~1 00 -1836.36 ~81 00 -1836.36 4~I 00 -1836.36 481 00 -1836.36 481 O0 -1836.36 ~I 03 -1~35. 08 4~1 I0 -1~31. 481 481 45 -1815.82 481 75 -1804.27 482.16 -1790.16 482.70 -1773, 50 4~4.33 -1732. 54 4~5.49 4~6.93 -1681.46 488.71 -1652.15 490.87 -1620.34 493. 4~ -1~86, 06 496..58 -1549.31 500. ~4 -1510. 11 504.52 -1468.50 .506.09 -i~54.74 511.17 -1410.62 31~.Y0 -136~.~ 52~.68 -1323.26 529.12 -1279.53 536.00 -1235.78 ~43.34 -1192.00 5.5!.13 -1148.20 D~9.37 -li0~.39 568.05 -1060. 57 577.19 -1016.75 586.77 -972.93 596.79 -929.12 607.26 -885.32 618.17 --~l,~ 62~. 53 -797. 76 641.32 --754.02 633.55 -710.31 663.02 -~77. 55 675.66 -635.08 6~7.9~ 699.89 -557. 39 711.33 -522.22 722.23 -489. 53 732.52 -459.33 742.15 -431.63 759.21 -383.~2 761.91 -376.72 771. 9~ -35~. O6 10:56 CLOSURE DIST. DIR. 2040 SI4E 2040 S14E 2040 51~E 2040 SI4E 2040 S14E 2040 S14E 2040 S14E 2040 S14E 2040 ~14E ~040 SI4E 2040 S14E ~040 SI4E ~040 SI4E ~038 SI4E 203~ S14E 2028 SI4F ~019 Sl4E 2008 S14E 1994 S14E 1978 S14E 1959 514E 1938 S14E 1915 S15E 1889 S15E 1861 SISE 1830 Sl6E 1763 S16E 1726 S17E 1688 SI7E 1675 S!SE !635 S18E 1~96 S19E 1556 S20E 1518 S20E la80 S2IE 1443 S2~E 1406 S23E 1334 S25E 1300 S26E 1266 S38E 1233 S29E 120l S30E 1170 S3~E 1141 S33E 1113 S35E 1086 S37~ 1067 S38E 1043 S40E 1023 1005 SI4E 989 S46E 976 S~SE 965 S49E 955 SS1E 947 941 S54E 939 S54E 937 S5~E DO0 LEO 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ~ 5 1 5 1 3 ! 5 1 .5 1 5 1 5 1.5 1 5 1 5 1 5 1.5 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 1 5 I 5 1 .5 ! 5 1 5 l 5 1 9 5924.00 12.00 N45.00E 5628.24 -515. 6024.00 12.00 N45.00E 5726.05 -500. 6124.00 12.00 N~5.00E 5B2~. 86 --489. 6224.00 1~ O0 N45. OOE 992! 68 -471 6324.00 12.00 N45.00E 6019.49 -456. 6424.00 12.00 N45.00E 6117.30 -44!. 6524.00 12.00 N45. OOE 6215.11 -427. 6624.00 12.00 N45.0OE 6312.93 -412. 6724.00 12.00 NSD. OOE 6410.74 -397. 6824.00 12.00 N45.00E 6908.55 -383. 6924.00 12.00 N45.00E 6606.36 -368. 7024.00 12.00 N45.00E 6704. 18 -353. 7124.00 12.00 N45.00E 6801.99 -338. 7174.00 12.00 N45.00E 6850.89 -331. 7224.00 12.00 N45.00E 6899.80 -324. 34 785.33 -338.50 939 S57E 2. 1 64 800.04 -321.04 944 S38E 0.0 94 81~. 74 -303. 37 949 S59E O. 0- 23 829.44 -286. 10 954 S60E O. 0 53 844. 14 -268.64 960 S62E O. 0 83 838.84 -25l. 17 966 S63E O. 0 "~ 873.54 -233.70 972 S64E 0 0 43. 888.24 -~16.24 979 S65E n_. 0 03 917.65 -181.31 99~ S67E 0.0 32 ~32.35 -163.84 1002 S68E 0.0 62 947.05 -146.37 loll S70E O. 0 92 961.75 -128.91 1020 S71E 0.0 57 969. 10 -120. 17 1024 S71E 0.0 2~ 976.45 -11'1. 44 10~9 S7~E O. 0 CHAN~E' (W>ELL (M>ETHOD (V)ERTtCAL SECTION (C)REATE A FILE (T)RUE VERTICAL DEPTH (P)LOT (A)L~ERNATE FORMAT (O)UTPUT UNITS (E)XTRAPOLATE TO TARGET (S>TOP (DEFAULT) .............. ~-' "', !., '-' ' ' "Alaska:.Oii & Gas Oons. Commission _ RECEiYED'- SE? 0 4 TRADITIONAL, UNITS 1 q " '~'~ 2:00 98~-u8-=~ 1 TRUE VERTICAL DEPTH 0.00 20O. O0 400.00 600.00 800.00 1000.00 ~.oo 1400.00 1500.00 1800.00 2000.00 2200. O0 2400.00 2600.00 2800.00 -3'006.' Oo 3200.00 3400.00 3600.00 3800.00 4000.00 4200.00 4400.00 4600,00 4800.00 5000.00 D~O0. O0 5400.00 5600.00 5800.00 6000.00 6200.00 6400.00 6600.00 6800.00 7000.00 7200.00 7400.00 RADIUS OF CURVATURE METHOD · (-~NO. I(WELLi7 > TO(MgSIO > TD(MgS14 > NORTH EAST FROM NO. 1 FROM NO. 1 -SOUTH -WEST FT DIR. FT DIR. -1982.00 -1982.00 --1982.00 --1982.00 --1982.00 -1982.00 --1982.00 --1979.98 --1968,5~ --1946.51 --1913.71 --1869.84 --1814.55 --1747.35 -1667.65 -1575.29 -1478.58 -1382.18 -1286.'16 -1190.55 -1095.91 -1000.78 -906.73 -814.05 -731.01 -660.89 -602.77 -555.95 -519.93 -489.=~= -459.46 -429.40 -399.3~ -369.28 -339.22 -309.16 -279.10 -249.04 TRUE TO (MS~IB VERTICAL FROM NO. 1 DEPTH FT DIR. 481.00 481.00 4~1.00 48100 481 O0 481 O0 481 00 6. O0 5 56 5 90 7 46 4 32 21. 57 63. 32 Ngow 84.81 N52E S73W 88. 16 N51E 5~2W 91. 5D NSOE S34W 105.50 N46E S°°~ 127.41 N41E N 7W 167.00 N35E N 3W 243.,72 N28E . 481 04 481, 83 482. 86 484. 65 487. 55 492. 07 498. 508. ~6 520, 96 535 552. 47 57 !. 60 59~, 9 6!6. 41 6,+.~. 09 669, 78 -9 ' 7RO. 60 759. ~6 781. 48 811. 841. 871. ~7 901 931 39 961 45 991 O~ 1 OTP 051 63P 121 53 lag. lO 271.75 392.43 553.95 911.18 1090.88 1288,50 1478.45 1651.91 1836.11 2023.00 ~!9D. 67 2369.70 2544.92 2714,80 2897.71 3083.96 3261.70 3456,77 3630,09 3778.03 3926.38 4074.82 413D. 64 4195.00 4254.66 4314.62 4358.52 4371.62 N 1E 320.44 N25E N 3W 428.32 N~OE N 6W 538.90 N17E N 9W 657.36 N14E NiOW 773.30 N13E NI1W 890.01 NIlE N12W 995.24 N10E N13W 1097.70 N 9E N13W li90.93 N 9E N13W 1293.58 N 8E NI~W 1391.89 N 8E NllW 1487.51 N 7E N10W 1575,87 N 7E N 9W 16~6. 34 N 7E N. 9W !729.46 N 7E N 8W 1779.47 N 7E N 6W 1818.93 N 7E N 4W 1847. 16 N 7E N 2W 1885,25 N 7E N !E 1912. 16 N 7E N 3E 1950.71 N 7E N 5E 1986.47 Iq 7E N 5E 2019.44 N 7E N 5E 2051.89 N 7E N 5E 2082.97 N 8E N OE 2ii6.9~ N SE N 4E 2153.60 N BE N 4E 2190.33 N 8E N 4E 2224.88 N 9E N 3E 2259.37 N 9E N 3E 2294.32 N 9E TO( FROM NO. 1 FT DIR. TO( ) TO( FROM NO. 1 FROM NO. 1 FT DIR. FT DIR. TO(MGS25GY ) FROM NO. 1 FT DIR. 9.06 S 6E 9.55 S12E 10.75 12.60 S41E 15.65 S53E 19.48 S59E 23_.72 S63E 29.07 S64E 40.58 57.83 S48E 68.44 S43E 79.89. S33E 104. 19 S22E 142.67 S14E 195.88 S ~60.19 S 5E 321.70 S OE 380.75 S 5W 438,90 S10W 495.03 S14W 546. ~6 S17W 590.87 S20W 631.75 S23W 672.44 S25W 705.30 S27W 724. 19 S29W 704.44 S34W 666.55 S38W 623,65 S44W 586.06 S50W 564,62 S57W ~57.17 554. 18 S66W 555. 11 S69W 555. 10 S70W 544.55 S72W 522.92 S73W TO( FROM NO. FT D'IF 0.00 200.00 400.00 600.00 800.00 1000.00 1200.00 1400.00 73.4i N52E 74.23 NS1E 75.88 N48E 79.33 N43E 85.55 N35E 93,0I N29E 112.25 N19E 131.89 Ni2E ;kECEIVED Alaska Oil & Gas Cons. Commissbfl Anchorage 1600.00 1800.00 2000.00 2200.00 2400.00 2600.00 2800.00 3000.00 3200.00 3400.00 3600,00 3800.00 4000.00 4200.00 4400.00 4~00.00 4800.00 5000,00 5200.00 5400.00 5600.00 5800.00 6000.00 6200.00 6400.00 6600.00 6800.00 7000.00 7200,00 7400,00 CHANGE: ro ~ ¢/,z~ 157.58 N 8E 185.73 N 7E 206.22 N 6E 240.66 N 6E 263.63 N 6E 292.33 N 6E 313. 50 N 5E 344.30 N 3E 389.20 N 1E 461.18 N OE 558.47 N OE 659.44 N 1E 762.19 N IE 837.98 N 2E 912.39 N 2E 978.31N 2E 1055.67 N 2E 1159. 19 N 2E 1274.85 N 2E 1419. 15 N 2E 1576.81N 2E 1742.03 N 2E 1909.70 N 3E ~077.9~ N 3E 2245.94 N 4E 2411.76 N 5E 2571.88 N 6E 2721.41N 6E 2866.41N 7E 3011.84 N 8E (W)ELLS (M)ETHOD (D)EPTHS OR INCREMENT (O)UTPUT UNITS (P)LOT (S)TOP (DEFAULT) kECEIVED C' Alaska Oil & Gas Cor]s. Commission Anchoraoe TRUE VERTICAL DEPTH TRADITIONAL NITS 1985-08-29 :'15 RADIUS OF CURVATURE METHOD ~oPos~ ~. ~NO. I(WELL17 ) NORTH EAST -SOUTH -WEST 0 ( MQS5 ) FROM NO. I FT DIR. 0.00 -1982.00 481,00 84.05 NSOE 200.00 -1982.00 481.00 88.60 N52E ~00.00 -1982,00 481. Q0 ~3.45 N48E 600.00 --1982.00 481.00 98.55 N46E 800.00 -1982.00 481.00 103.93 N43E !000.00 -1982.00 481.00 126.32 N36E 1200.00 -1982.00 481.00 151.03 N31E 1400.00 -1979.98 481.04 213.62 N25E 1600.00 -1968.55 481.28 268.49 N23E 1800.00 -1946.51 481.83 334. 11N22E 2000.00 -1913.71 48~.86 400.~ N2~E 2200.00 -1869.84 484.65 467.50 N22E 2400.00 -1814,55 487.55 540.54 N22E 2600.00 -1747.35 492.07 608.23 N22E 2800.00 -1667.65 498.82 678.01 N21E 3000.00 -1575.29 508.56 732.04 N20E 3200.00 -1478.58 520.96 774.47 NtgE 3400.00 -1382. 18 535.57 817.86 N18E 3600.00 -1286. 16 552.47 864.39 N17E 3800.00 -1190.55 571.60 912.91 N16E 4000.00 -1095.41 592.91 967.10 NI4E 4200.00 -1000.78 6!6.41 1015. 16 N13E 4400.00 -906.73 642.09 1045.67 N12E 4600.00 -814.05 669.78 1071.59 NllE 4800.00 -731.01 696.52 1078.06 NIOE 5000.00 -660.89 720.60 1098.00 N 9E 5200,00 --602.77 741.61 1104.6~ N 9E 5400.00 ---D55.95 759.26 1120.24 N 8E 5600.00 -519.93 781.48 1129.43 N 7E 5800.00 -489.52 811.15 1128.46 N 6E 6000.00 -459.46 841.21 1127. 15 lq 5E 6200.00 -429.40 871.27 1109.41N 4E 64-00.00 -399.34 901.33 1092.24 N 3E 6600.00 -369.~8 931.39 1072.49 N 1E 6800.00 -339.~ 961.45 1050.93 N OW 7000.00 -309.16 991.51P 1029.58 N 2W 7200.00 -279.10 1021.57P 1003.55 N 3W 7400.00 -249.04 1051.63P 978.08 N 4W CHANQE- (W)ELLS (M)ETHOD (D)EPTHS OR INCREMENT (O)UTPUT UNITS (P)LOT (S)TOP (DEFAULT) -. , - : · .. -.,. . . · . . . ., .°- . · . . _~_'_~-T ~m~ Amoco Pro{:tnctf6~ Company AMOCO~ DRILLING AND COMPLEYION PROGRAM mE NO, II~ OATEJuly 17. 1985 .~$E_ Middle Ground Shoal 17595 ~m NO. 17 FIEm Middle Ground Shoal :OUNrY Cook Tn]mt. Alm.~ka [OC_A~ON Top of B Sand, 500'FNL,800'FWL,Sec 31, T9N,R12W )8JECT: Develop reserves by expansion of the BCD horizon waterflood. METHOD OF DRILLING TYPE TOO{S DEPTH INTERVAL Rotary ~-Surface-TD SPECIAL SURVEYS DEPTH INTERVAL, ETC. TYPE BHg-Sonic/GR BSC-TD DIL-SFL BSC-TD FDC/CNL/GR BSC-TD ~DT BSC-TD 'b~rp Survey BSC_TD (Et, gkRKS . Gyro run at district discretion to confirm magnetic survey data TYPE None scheduled SPECIAL TESTS DEPTH INTERVAL. ETC. ~RKS APPROXIMATE DEF;THS OF GEOLOGICAL MARKERS .~,~TED EL~^T~ KB~79' ' M~J~CE~ I De'TH J ELE~AnON Tyonek A 5280~ TVD -5201' SS B #* 5720'TVD -5641' SS C #* 6150' TVD -6071' SS D #* 6460' TVD -6381' SS E #* 683Q' TVD -6751' SS; TOTAL DEPTH 6900.! TVD -6821SS · Possible Pay ~ Probable Coenl~e~°n In,er*ol DRILL CUTrlNG SAMPLES J DRILLING TIME EREOUENCY DEPTH INTEI~'AL] FREQUENCY D~PTM INTERVAL ~0' surface-BSC Geolograph surface to ~ L0 ' BSC-TD REMARKS: - Note: Geologic markers should come in approx. 10C high to HGS 17595 #13, closest offset well. Wellbore deviation m~ cause estimated tops to be in error. ~UO PROGRAM APPROXIMATE ~TE~AL TY~ MUD WEIGHT 0-600' Spud Minimum-9.5 600-3200' Gel/Water Minimum-9.5 3200-7200' LSND Minimum Vl~O~ SEC. AH ~L CC/30M O~EE ~ECIFICATK~XNS As required to clean and stabilize hole As required to clean and stabilize hole As required to clean and stabilize hole Mud properties to allow for effective logging, casing, cementing and testing operations. Weight up only as required to control gas influx in Tyonek group sands. :ASING PROGRAM CASING STRING :ONDU(TOR ;UI~FACE ',,IT E b~E DIATE )IL ST~JNG INER CASING EST. DEPTH CASING SIZE' HOLE SIZE* 600' 20" 26" 3200' 13 3/8" 17 1/2" TD 9 5/8" 12 1/4" SX. CEMENT ~ C~ENT DESCIIIPTION OF ~NDING ~INT. ETC. Surface "O"w/additives '~ipple up 20" diverter Surface "G"w/additives Nipple up Bop stack 500''above- Set 9 5/8" to~TD if posgtble Tyonek Group 13 3/8" surface casing point selected to place angle build section behind casing and to top set,Beluga gas sands which may have gas potential. Run 9 5/8" to total depth as production :i~:?ii~ii:-:::.~!:!i!':'-i~:~iii:/.~?:;i~:/~:,!:-,?'' i':'.?~i=~'!-:~i:':-:I ~!5 casing, if possible. :, :z-~v ,.~'~-5~ L r-~ ~ -~,.-'; "m'-,<-~.~..~--.*~-~':-'m~'' ...~.~..~'..~.~-':s~:.:: 'Noe'mal. the lut~br geo~ ollocofic~ leltes' specifies casing sizes to be used. Hole ~izes will be governed by contrad. :ORING PROGRAM .. / -. ~. _ -_ . -. . . . . ;r' ':.-. -- :' _ - ; . ; . -_ . - : - ~ENERAL REMARKS We[[ ~o be d~ec~ona[[¥ d~±[]ed E~om?]aLfo~m~aker, ~s~ma~ed TD ~s 7200~ w~h 26~ maximum wellbore inclination. :OMPLETION PROGRAM To be recommended by District and approved b7 Division. i. 500- 1000- 1500 - 2000 2500- 5000- 5500 - 4000- 4,500 - 5000- 5500 - 6000- 6500 7000 -2000 · sUR'FACEi · : ... ......... · ....... i ................... ~ ....................................... , ........................................................... ? ................... · IFILE = WELL17 ......... · ....... -" ............................................................................... [Vertlcol Section ....................... · :: I 18.89 Degrees : ! IUNITS=FT ......... · ....... :.. ........................................................... , ............................................................................... _ ® : · : ; · : · · .. -1500 -I000 -SO0 0 500 lO00 1500 2000 .~',!aska Oi~ & (~]a$ Cons. Anchorage PLAN -TOP- VIEW FILE- WELL17 UNITS - FT 1500 I000- : : i : .................... i ................... ~ ................... :. ................... ~ ................... ~ ................... ~ ................... : : . . . ~..,¢''/ :: : : ~ lTD -.- .................................... ;. ................... : ................... i ................... : ................... i ................... : SURFACE I I I I 500- -500- ~" -1000- 0 -1500- -2000 o 500 1000 1500 2000 2500 3000 WEST EAST 3500 kECEiVEI_) Alaska Oil & Gas 6o~s. Anchorage SUBJECT Amoco Production Company ENGINEERING CHART Sheet No. Of File Appn C Amoco Production Company ENGINEERING CHART SHEET NO. FILE APPN ;: ;: (~z.' aoo / /' HYDRIL / LAN NUL/1R BOP) s HAFF-~P, /~//. L Z. /A/E ! L~93 ! SNA FFEF, -rD I~nl~i roi J) (,--/" z..,,.,~ } ,X EC E iV E D Alaska Oil & Gas Cons. Commission l~,.nchorafie 31 LEG [:0. I .LEO .~.'0 2 '- L~.T 60°49'45.75" i ' LA.T. 6004:3. 45.~Z" LONG 151°29'00 95T LON$ 1513 29' O0.O7" Y = 2,498,059.8 . y = 2,.49-3,014.45. X = 235t 255.0 X -- 235,297. :30 ' F~0~! l'l.;v- COR. FROM NW. CaR. ' t954' SOU3~H 8, . 1989' $OUT~ ~. 5~14' EaST 588' EAST . . . · I h.=reby licensed s.u.rv.ey. that oll Date . SCAL~ :~"":.lO00'.. '~!~ - ' :' ! 6'' T8N " "'""';" "' '~1~ ' -. . 'LEG ,'<i;:]) 3 --~. LAT. 60° 49' 44.70" - .. _ LON~ 151° :>9' Gl. 4~" -- ' y-= 2,49_7',g~3,.55 - X '=. 2:~5,230.30 FROM. N.W. CAR.'*. 2041 SOUTH ~ · - . 5~2 EAsT : .. .. . . - · . · ' · .. ., - · . ~ ~.,¢..,_~: . .. CERTIFICATE OF ~'~/~(~a$ C~r~s.'Oor;imiSsion ' .~,nchora~e' ' -certify that I am properly, registered and to practice land surveying in fha State 'of and that this plat represents a location mcd~ by me or Under my supe~isidn-~nd dimensions end other details are correch. S u rv eyor~f~ · o o NOTE The location of platform legs was accomplished by using U.S.C.& G.S. monument's Tad, Boulder,and Cost, BLM c~h- trol points CET I0 ~ and Granite Point Native Hub, and triangulation stations East Foreland Light Offset, and Arness 'DocR. 3l' 32 COOR I'NLET CORRECTIO;t LltiE · . , ... .' ,. i LEG N~Oi~-" . "' " LAT. 50° 49' 45.25". · ~- -r'"'.%"~'%~-~-'% . ~ "LO~ [~10 29~ ~.'~"" ~ ~ '~ ~ ' · ~'.'c:Oi' 4/ ~ - X= 235, 187.7~ '-: ~'"'. '," " · ' ] ",. '~e '~ -~ TM F~O~ N.~ CO~. ' .... ~ ,~ .... ~ · . ~ .-. ;.' .l] .~.' . ; ~ ~, ,. - ~' . ~es~ s°u~, ~ ~o~.:.~ ....... ~'-:""c' - ' " .r, - ~.~-. ~. .. ; ~-.-. ~ ~' -f - t~ ~ ' N-.. '.~'~ ' . , ~ %,.-, ,. . ~.~ '. '" ~,.,-. ~-~f...c~.',-_ ' · ; " '. '~-" / (~'"W. ·" ..... · %'.,., ,... .',-, .... , ,.. ','--~ . · ,,..~,,...: _%.;- - . .. . LOCATION SURVEY OF A FIRST ORDER CONTROL POINT "PA H" OiLI PLATFORM "B" '~"ATcD ;ti ,~l/-~.?~'~' .,.~ _ · ....... SURVSYED FOR PAN AMERICAN pETROLEUM CORi -. .,-. PO 9OX 779 A~CI-!Oq&GE, ' · SURVEYED BY' F. M. LII'.!DSEY 8, ASEOC.. LAND SURVEYORS 8~'CIVI~' ENGINEERS August: 20, ].985 (, W. O. ~mith- Anchor~e Subject: Tubular Goers Allocation Middle Ground ~s ¢1o. 17 Kldclle Grour~ Shoals ~ Inlet, Alaska 846650~0 ~L ? Ltste~ below is the oasing design/allocation for the well. 600' 20.000" 94.00% K-55 BTC Kenai Sthse ~ District to recur STC in Kenai Sthse to BT~. afor~ention~d 3400' i3.375" 68.00# MUSt drift 12.25" BTC 50A-4019 (85) Denver 80' 9.625" 53.505 N-BO 5420' 9.625" 47.004 N-SO 7500' Must: dztft 8.5" ~ 50A-401B(85) ~ Denver BTC 5 0A-4018 ( 85 ) Derive r TO be designed/allocated late=. W.R. ~alvorson SFP 0 G. ~~e- ~t Division Well Pile - ~B. ~ 1539 ~ ,~,'/,~N ~ ' C~nts:~e ~e c~i~ design is b~ ~n a '~'9;5'~]~. 8 w~iaH,_ for g g xn~e~tate file reference: mgsl7 Sheet No. Of Amoco Production Company F~le ENGINEERING CHART Appn SUBJECT /¢/v 7-/(2/P~ ~.~A-/A4 ob,¢ ~ ~0~ Date _ ~----;~i ...... ~ ..... ~'-~ .... ~-~'~--:,;~--7% ..... ~ .... 7-"f .... T-i-%: ...... ~--'-~ .... 7 ...... ; .... ~-/-~. F ! , ~ ; . : ; ~ ........ ,=._: ............ ~/ 2 .... /f_ .2. ~;'.__j ...... ~ . 2¢.7 .... ¢", .... , .. ~__~ ' ¢ f t---'~ ....... F~:~-~~ ~t~'t ' ...... r .... '" --; ...... ~ ....... -----~ ~-----~ ..... ...... .. C IVED (AMOCO) i i Amoco Production Compan~ ENGINEERING CHART SHEET NO. FILE OF APPN DATE ~-~'- """"' ?'"'"' 4~. ' -- CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee '~'(2 thru 8) (3) Admin ~_~_. )-- &-0~.j 9. 12) lo. (10 and 12) 12. -(13- tl~u 21) '- (22 thru 26) Geology: ' EngiBeering: WVA~ MTM ' HJH~,M~ rev: 03/13/85 Company Lease & Well No. YES NO REMARKS 13. 14. 15. 16. 17. 18. 19. 20. 21. 1. Is the permit fee attached ......................................... 2. Is well to be located in a defined pool .................. ' ...... 3. Is well located proper distance from property line ..... !ii !i!iiiii 4. Is well located proper distance from other wells ......... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included .... 7. Is operator the only affected party .................... 8. Can permit be approved before ten-day wait ............. 22. 23. 24.. 25. 26. 27. Does operator have a bond in force ................................. Is a conservation order needed ..................................... Is administrative approval needed .................................. Is the lease number appropriate .................................... Is conductor string provided ........................................ z~Z Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... WillWill all surface casing protect fresh water zones... ......... ~i~';~d '/Z~f~ casing give adequate safety in collapse, burst..... Is this well to be kicked off from an existing wellbore ............. .4 Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation Proposed ............................ ~ Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~aoo psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements .............................................. ! Additional Remarks: / INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,, , ...... 0 HO Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXl .. No special'effort has been made to chronologically organize this category of information. ¢ , ,.4 -? -, _ . ~, ,. , , ,: ,~, · .. · 1 "] m', I .,'t '7 ,~ ,.. ,,,. . ., ".,':.:. 7' ~, . . 17.' .,,, "',, ... · ~,. · ..... ~.':-.. ,": T" .... .~ .:. :;", ~ ~ '" 'I .... ,, !'!'." .... , ~, 1 .-",.. ?.."!. ":," q / ~, , "' ,, ':.. '!'.i. ':'..~. ,, '..~ '.:, 1 2 ,, ! 7 1";',, !!'~ ,-,, I '::.'~, ii},' 1 ',/' ~ ''''~ 1 '":;~ ,, ':? '/. ?: 0 ,, i....' 4 .,ii,, 'c.: ?. "t~ ,' ? . '7 '? ~ '~ ', ..... ',? ~ 1 7 ~.; . ".i: ~:...~:~:. , t ! ,,, "l I ! ,, i "'.:. ';!., ~ .,.,. m, 1 ' · '~, - . . ,~ m . . '7. ,:;,. ~ ~t. ',': ,.. ,. ::'; . [~', :,,., ::;'. :,':': ! '~ '""· 7' ' 1 ' . t 9. ,'/,:; ",'"" ,~ 7 .", .... ~ ., , 15.. ....... :..',~ ,, ? ::/~ ?' I 1 ;.::~ . '.'.'.::~ ':.'.7' '~ .~f~.. I i '<,. ~ '! 'F !f.,~ '~,"~ ~ ':' .,.., ! '"~ . ! ,, 7' I '? .. ,: .'.~. ,. ~".:., 7' ,:t .... ..... ~ , : .... 1 ! · ".. 7 ..... ,::, ', ~ ,.. 7,',. ~ i i. :? ,~- '.'7 ~ . ~- ] '~ , . , '? t~ : .'i, , ? '":' ,~ '? r ,, ,, ~ ', : . }~; ~ .,:' .... , . ,:.',' , .-:. '!, I, t ' .... , . . ~-., .::'.. ,, ? .'~.. ,~! ~ ~ ...: "?,~ '~ '., 'L~' ~' /. ~,-¥ I ::; ,, ":,. ' ..... .~ ..... ,,~ '1 "". ?' ',:' I ;.. ";: ?, . '"-' ! '7. ?' 1 ;~!;. 1 "::: 1 ' . t 1 '?". 't "~' ,,,~ :;:::. 1 , 7'~ ;;!!',. '?,, ,?. ? 'C 7 · ,:!I '~.. i:,!' ":? ~:.. ,::',,, -?, .... ,,::: t ?,, ':';' "i':; .,:!!:.. (i.:.~ ,,-~' I ? · ":', ! -!:i, 7' .,'. 9 · '" 't '!., .. t ": · .. "~ L' 1 !?, .... ..:, ..... .~:, ;,-, ,.. ',' ~ ', '? 'it? , ~,.';' ,,., .., i I ., ,, i "" , ? ~,~'; , ~ 'i I ',',,:~,, ,, "? ,~':. '~,, T. '" i ......., , . , .:.: . ?:'~ ,,~,., / ,,, .. r i ! . I ........... i ........, ,' i RECEIVED Alaska Oil 8, Gas Cons, Cornmks/ort Anchorage . a, i,'i,, '~ ~, · 1" . ~ ~' 11.{. ? I 1 . 7 C i ~, e ": '"'~ ! ;:, '" :~", , 11 .>! I I , ,', 11." ', ~ ~, ~? '../ 1 1 . 1 t, 1 1 1 ~'''' .. c, ? 1 t . {'. '.?~ ! 1 · ':: ,,,,, ' I , · 1 .-,, · ! I , :i, !I i ~'. ,7! "~: I ,, '? ? ...... , ,,~ · ,, 1 'I ,, I 1 ,,, ?' I I , 7 I I , '''~ a, '*] T' , ,~ .,, i 'i ,,* % , . I t ,, ,,, '"i /1 , '"~, '] 1,,; , ! ! ,, :'~ ' 1f ' , ~, ,".'; t I ,, I 'I,, .) "i "'" r~ ..... ,-/ ~' ~ ..... ?, ,-~ ~ ,,,,~ i ,'}, 'i" ~ 1 I ,, ";: '! I ! ,, 5" 1 i ,, ? '" 1 1 . .4 I I. ?" "!~ '1 i ,,, ' ~ !~,,. ,, -~,, .~ . ~ · .; . : .. ~. "~'7: n _. :' ~ ,,,, .' ,,~ '~,, 'I ? ,, ':' i ~ I ~ "i,' , ', ., ~ ,~ ..; .: ..., .., ~ .... ,] ~-.,'. ~ · ,, . ~ , · '1 I , - - i.',i- ~ ,' · 'i ·': , i ~ ,- I ':i: · '.~ ':~ I ! , 7 :'. 1 1,. ']. I ";'~ . :'.;,' 4 I ~' ~ ~:, 1 z,., "~; ,; I '? ," 1 t z.. '? 1 '"~., :'". ..~ . , .; I 4 ,, '': - I ~;, "'" I -:;:', 1 '1 .';, '" ,~ -. · ::::A I , I '7 1 '., :.':' 'I v ::,, J 'I t .!,' 'l ", I 1 . ~ · ,j - · ; ",', !7. i ".': ... 1 ,:,.. '" I I ~,, ' 1 I 1.7 ' !!,,"' I 2, ~ 't I P., "': ':'; ! ! . .c '.' i ! ~ ":',; i I "t, .'": '~ 1 i]!..., .fill 7' '"l '~~ ~J .... ? '~'.i ,,;.i.'. 1 ! ":' . ,('.:~ '1.~!':, ".'!!. "' 1 .'~., ";: .... ! ,','iii, * ..... ! t , ].:" '!i'i:', (': ~ .". '! c. ,, "' t '; ,~..,. t ':.i;., '71 S - - ,. 2- ', 1 :. ! .,.-' ' ., . -.I, · ~ ~, -., -' ,",,. '. ,,' m.r''' t " I' · .. 1! //-:.. ! i ..... ,, L ..~'.~. .~ , ,,, "7 ~ . .' ~..: ...... .,! ,' ...... ,.,i .. , " ~'. ,4 ", ? ' I ',"a 'i . '!'"' ~(., ~ '"" ...... i 'i'.., ":' ' 7' ,, f.':. :' '! ~" ,, '" I I':,~ ':" "11 ! ' I ..... 1 ,,. '1 ~ .,u . ) ,, '7 ". 1 I .... ,.1 ~i ~ ! J',, ":'i I ....~ i 7 ! ":~ ,,, 7' .... ! '!i' :': ,, :"' ,:'i.. 7,, : '". '~ ,, -,' u, . i"',' ~" . .~ ' ~"- il . · ., ,,: . ~ ! ~B '" ,lC '~ :-: . 'I" ,-: -p ,: '~, ; ':~', ?., '7 ' .. ': ':: ! "" "2.. ::" .... '"I ,~ 3 ':'" '::{ 6 .. ,? ":': ~':,, ,~, . ":': :.~ ;:~,. 'l. · '"'" .... ,.~' ~ 2/.....!:' }:,, ..... ,, ':::~ '?' "~i. ,':'~ ~1 :,:': 7 ,, ! '? ~? ,,, 6 ':," ?: {;...,.:, .~ .... · ~',. ,::+ :?. "~ RECEIVED Alask~ Oil & r~as Cons. Cor~rnissio~ ., Anchorage · .., .,' ,ir .~ ,. ,. · a . i I . ':. i1,11 . . ::' 2 ' 5': I1," '? o :::.....) '1 '! ~ ',5 I ':: '1 ! ':.'. ~ '.' ':'7, . ':? 7 '~ ~:, ~:?: '.3 1 ~=']"~, '::'. ,.:~. '1 7, ::," 1 '.:'; · ? I ~ '";~'' ,::'. ';:~' ~ (': ,:~:~ I :C;:. '~?,f ~ '"' ",~, C;',' ! "". ;,, ., .,.,.. ,~. ,. .... '":' · C "' ,, i I ,.. ,~ . , ...... '"' ~, ~, 'i . i;'il ,~, "~..,.~- .? ,~, ' "7' ' i' ,. .. ".2 · ~ ' . . . ., ,: . . 7 ~,~, .,,, '? ': , · . '? ,~ ;.'i !.i. ;" '! r '? ';7 .. .. · ,v. .... ; .;., ? .. '? 7' .. . ,~, ,..'., ,?.. .. .. "... ... .'~ ~ 7~ ' ¢'; · ·' ' '7 7 ,,..." I -*' "Z.. ¢ "> .. ,:.'. ~ . --) ".'~. ~ ' ... ',:, 7.,, 7 ' 1 · ";:' }' ':: ~,,i} '7. ..:., 'i!! .... ¢~ :~'.~ . "T "? ~?'~ '~ '3. '"" ". '? c;, T: .¢ , ,~. 0 . J,,.' .... '}'{. ?.,,, :7 ~':' :'j;,;: ,, ,,, ¢.'.!. !7 ,,, '? A 1 ,, ' 7 ,,!,,,. :?,,, ,, '-, "7 .::ii ':(! ,, ,.::' 7 '7 ") C,. 7/ ,,., ::;' !; ,, ":' ~.'.:. :!!'~. ~ r ,. ~:'.:, ~ 7 . .' .:.. ':?.. ,::',, ,, ~ ! ':,", z:,,. ,, ,:::,. '! .::.;, ,,. '; ,':!, :? ,, ': ','? '!:, ,, '1 7 .- .. . . ,~ , .i ~. 1 "~ :;/ ,: " :., .. '.}, '? ~ ':: ::'/, I . '"? .": . .... '.:, 'J,', ~, d, r, "7',.' ,'L4 ~ q ,,,, .:,;: , ':} /...'~ , ¢.'.,. 7' ;.,, '?, ~ "' ..:: :",;, t.;':. '3 7 {': · :'? ": 7 ';':" ,, ~:; ": ...... , Z '~..~ ,~., ..,:. :,..., '7 '": , I t ,,".., ~:';' '~;, ,,,,: :;.i" · "? i"~,,, ?' ....:.:, ~:..: ..: ", ,' ~ f 7 · . ~ '? .j, ~ · ,. ':;' '} ,, ".:: '7:. ? ...... ;, ,. 7¸ j . S' , ,. ~ r ~ ..1 '": "~:' · .~ ~, . _ -1 '- ! 7. ! .' I :":,., ,:~,' I ,:;.':', :::~..'~.:., '1 ,::'',;: d ~,,~ , q ],:; . '" I ':: :.3 ...;~.. , ~ 1 :,. ~" ...... , ~ I ¢:.., '7 '? t }. "::: ':.': I ...... , '.7 ? ~ :,'; ~, ':" ,:,.,~ ! "::t , '::.7 .... I &:' ,. ::,'.;: ( '] /~,, ,::,~-,,'.:: I ~.',., .:: '7' I f", ;:'} 7 'I ::.' ,. 1 ') ,:.,:, , :>! ! ':' ,.'.~: .~'~ ,,]. ~ ., i '~:;: · ':":: :"' I , :'::' ': ~ ,:' .,-, ~ ,, ~ '" ~ ;' .,. i ~ ..... 7 'I . '¢', ':,~ . ~ . i:' ? '1 ' l, .. ~ · II ~ ~ 'l ? I~ [ I ~:l II .... i lll' , .... "5 . ~l ,2~l, {[~ mm iI m { { } l~{ ljl~' ? · <? .... {i ........ , ii /[~ ' I i~ ,-~ · , , ! ... ,. .3. ~i ,b 'i: ,~ '"i .!,.. ,. ~ . ,..,., ,,,, , ~ ' .. ~o ,~ , i 1,7' ~ '? -? ,. .., e .'~.~ ~ ,., ~ 4 ~ :-~ ':" ,,~ ?. ? ..... , ~ ~., ~.~ , :',~, , ?, ,,~ ~ ..... ..,,. , ~ ~ X" ~.:, .... ':? ~ .~. '~;,, ~ . &.,/... f,, , "7 '?' , ~, -7 .-, · . ,.. ,] :, '", "3 ~ - ,~ .,~. .,~ ~: ', .. ~,,~ ..... : L., ,,, ~' ...'. '~? ,, ::' . ~, : ~ ~,~ ,o .. ~: ., . ., · . ,. · , .... ':ii!: ,, ':.i., il. ,, I ,~ r:-" 'l"i ):.. ,~ ,:;il .,:l: · ..,... , .. :':': , !!i: l"l ::)." ..l,, l? ! ' !!!: · .l .".?l ,. ,,., , '~ .... 'l}~l l}~ll I . ~ I1 ~ l. ',' ~ '~ '? m - & ~ . "7 ~ .. · '~ ,~ ,,,~ .~. ~ . .~ RECEIVED j/:,~ i', ~ "~'' '"' ~Alask~ Oil & Gas Cons. Commission ....... Anchorage' u , '""' .:"' m '.'. :' ,':.,, , ,,.1:' ":': ~ ,:'* .'2 ~ ....... ",:~ ~ T' ~. ,.: , ?.. .2. & ~ ::.. '" . . "'~~ '"~1' ' .. ,',:~ .::' · t '? ~,* ..... ..~, ',. ~ ',....; ,' ~:.', '.:~ · T .... .~..:. m '.' 2. ' 'f., ! ': ,.,,:' .?, :.,, ,, ,~'. [:: · .~.. ..T , .... '::i ~ "~" . . . ,. · - ,- -..: ~ ". :" . ,.. · . RECEIVED Oil & Gas Cons. Commission ....... , Anchorage
