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Home My WebLink AboutDIO 009~` Image Project Order File Cover 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. ZQ (~ ~ ~ Order File Identifiier II II~II) II III I I !II lil 1111111! Il Ill III Organizing (aone> TTwo-sided I `~ ^ Rescan Needed RE CAN Color Items: DIGITAL DATA ^ Diskettes, No. OVERSIZED (Scannable) I ~Maps:~,~~ N}g ( ~' )~ S ~l E l.~ ^ Greyscale Items: ^ Other, No/Type: ether Items Scannable by ^ Poor Quality Originals: a Large Scanner ~~COV°vTti~- CEw1 ~~T I~pO~TD OVERSIZED (Non-Scannable) 1-O ~r ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~.. /s/ Project Proofing 111 llllll IIlII II III BY: Maria Date: ~ /s/ Scanning Preparation x 30 = + =TOTAL PAGES---~~ (Count does not include cover sheet) BY: Maria Date: ~ ~/~ ~ '/7 (] /s/ Production Scanning Stage ? Page Count from Scanned File: ~~_ (count does include cover sheet) Page Count Matches Number in Scanning Preparation: _~ES BY: Maria Date: ' ~"~~, fff Stage ? If NO in stage 1, page(s) discrepancies were found: YES BY: Maria _ Date: Scanning is complete at this point unless rescanning is required. NO lsl ' - Y NO IIII!IIIIIIIIIIIII ReScanned BY: Maria Comments about this file: Date: Quality Checked 81111111111119 10/6/2005 orders File Cover Page.doc Index Disposal Injection Order 9 Kenai Gas Field Unit Well KU 11-17 1. October 5, 1994 Unocal Application for Injection Kenai Gas Field Unit Well KU 11-17 2. October 13, 1994 Notice of Hearing and Affidavit of Publications 3. October 10, 1994 Unocal's request for Class II Disposal Well Kenai Gas Field Well KU 11-17 4. July 20, 1995 Unocal request for clarification of acceptable wastes pursuant to disposal injection order #9 for Kenai Gas Field Unit 11-17 Well 5. August 2, 1995 excerpt from regulations 6. August 7, 1995 AOGCC ltr to Marathon re: acceptable Class II Wastes 7. September 9, 1996 Marathon's request for waste management status 8. December 8, 1998 Marathon's request for clarification of exempt waste for class II well disposal 9. December 11, 1998 AOGCC response to 12/8/98 request 10. January 11, 1999 J AOGCC response to Marathons clarification on freeze protection 11. August 25, 1999 Marathons request for approval for use of defoaming agents 12. August 26, 1999 AOGCC response to 8/25/99 request 13. September 27, 2004 Proposals to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells 14. 2007 Kenai Gas Field Grind & Inject (G&I) Operations (Confidential) 15. March 8, 2010 E-mail re: Marathon and commercial disposal through G&I facility 16. April 15, 2010 Email re: Injection well KU 11-17 Disposal Injection Order 9 STATE OF ALASKA ti OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: The REQUEST OF UNION OIL ) Disposal Injection Order No. 9 COMPANY OF CALIFORNIA ) (UNOCAL) to dispose of Class II ) oil field fluids by underground ) Kenai Unit No 11-17 well injection in the Kenai Unit 11-17 well. ) Kenai Unit November 16, 1994 IT APPEARING THAT: Unocal by correspondence dated October 3, 1994 made application to the Alaska Oil and Gas Conservation Commission (AOGCC) for authorization to inject Class II waste fluids into the Kenai Unit No 11-17 well. 2. Notice of an opportunity for public hearing was published in the Anchorage Daily News on October 13, 1994. No protest or request for a public hearing was filed. FINDINGS: No wells penetrate the proposed injection zone within aone-quarter mile radius of the Kenai Unit No 11-17 well (KU 11-17). 2. Cook Inlet Region Inc. and Salamantof Village are surface owners within aone- quarter mile radius of the KU 11-17 and have been duly notified of the proposed plans. 3 . Unocal is the operator of the Kenai Unit. There are no other operators present within aone-quarter mile radius of the proposed KU 11-17 disposal injection project. 4. KU 11-17 was drilled to a total measured depth of 5400 feet, (4861 feet true vertical depth). The Sterling Formation consists of Pliocene aged, massively bedded, predominately coarse grained, fluvial deposits and is present within the KU 11-17 from approximately 500 feet measured depth to total depth. ~~ Disposal Injection Or~'f No. 9 Page 2 November 16, 1994 6. The proposed disposal injection zone is 4468 to 5152 feet measured depth (approximately 3970 to 4570 feet vertical subsea) in KU 11-17. 7. All aquifers below 1300 feet within the Kenai Gas Field Boundary, and one-quarter (1/4) mile beyond, are exempted under 40 CFR 147.102(b)(1)(C). 8. Approximately 2738 true vertical feet of Sterling Formation sediments separate the proposed disposal injection zone in KU 11-17 from the base of the non-exempt aquifers in the Kenai Unit. This interval contains an aggregate thickness of approximately 500 true vertical feet of impermeable confining zone lithologies. 9. Thirteen and 3/8-inch surface casing string is set at 1994 feet measured depth, cemented to the surface and tested to 2500 psi. 10. Nine and 5/8-inch casing is set at 5371 feet measured depth, cemented to at least 3000 feet measured depth and tested to 3000 psi. Cement evaluation tools run in KU 11-17 indicate good to excellent cement bond from total depth to 3000 feet measured depth. 11. Two strings of three and 1/2-inch tubing are installed with dual packers set at 4351, 4508, and single packers set at 4620 and 5003 feet measured depth. 12. The operator conducted a mechanical integrity test on KU 11-17 on 6/10-11/94. Test pressure declined 12 psi in 24 hours from 1000 psi to 988 psi. 13. Disposal fluids will consist exclusively of fluids brought to the surface as a result of drilling, production, and workover operations. Typical fluids will include produced water, drilling and completion fluids, equipment wash water, drilling mud and cuttings, and pipe scale. 14. Maximum injection rate is expected to be 3000 barrels per day. Average injection rate is estimated to be 50 to 100 barrels per day. 15. Estimated average injection pressure will be 1000 psi. and maximum injection pressure will be 2400 psi. 16. The estimated injection pressure parameters for KU 11-17 are based on step rate tests performed in two other Class II, Sterling Formation disposal wells within the Kenai Unit. 17. Athree-dimensional hydraulic fracture simulator run of a worst-case scenario with injection pressures exceeding the anticipated formation parting pressure, and using volumes of drill cuttings which surpass those expected for the KU 11-17 project, Dis osal Iri ection! No. 9 ~ Pa e 3 p J g November 16, 1994 indicates induced fractures will not propagate through the overlying confining zones and cause a risk of contamination to non-exempt aquifers. l8. The operator plans to monitor the 9 5/8-inch casing by 3 1/2-inch tubing annulus pressure and report the results on the Monthly Injection Report. CONCLUSIONS: KU 11-17 is constructed in conformance with the requirements of 20 AAC 25.412. 2. Well integrity has been demonstrated in KU 11-17 in accordance with 20 AAC 25.412. There is sufficient impermeable confining zone lithologies present in KU 11-17 between the top of the proposed disposal injection zone and the base of the deepest non-exempt aquifer to prevent injection fluid from entering any underground source of drinking water. 4. Disposal injection operations in the KU 11-17 will be conducted routinely at pressures less than confining zone parting pressure and will not initiate or propogate fractures through the confining zones. 5. The requirements of 20 AAC 25.252 have been met. 6. The approval of disposal injection operations at KU 11-17 will not jeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED THAT: Rule 1 Authorized Injection Strata for Disposal. Class II fluids maybe injected in conformance with Alaska Administrative Code Title 20, Chapter 25, for the purpose of disposal into the Sterling Formation interval from 4468 to 5152 feet measured depth in KU 11-17. Rule 2 Demonstration of Tubing/Casing Annulus Mechanical Integrity The tubing/casing annulus must be tested every four years for mechanical integrity in accordance with 20 AAC 25.412. Dis osal In' ti n Or r N . 9 ~ Pa e 4 sec o o g p November 16, 1994 Rule 3 Well Integrity Failure Whenever disposal rates and/or operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation, obtain Commission approval of a plan for corrective action and obtain Commission approval to continue injection. Rule 4 Administrative Action Upon request, the Commission may administratively revise and reissue this order if convinced that any changes are based on sound engineering practices and will not result in an increased risk of fluid movement into an underground source of drinking water. DONE at Anchorage, Alaska and dated November 16, 1994 g~~- or t ~'d o ~y`-- ~N ~. ~ S,M y~r1oN ~~ ~„, ~ z ,~r~ o C ~,'~. ~ AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Conunission an application for rehearing. A request for rehearing must be received by 4:30 pm on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Conunission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an 'application by not acting on it within the 10-day period. An al~ected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Coltunission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Conunission, the 30 day period for appeal to Superior Court nms from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). uckerman Babcock, Commissioner • • O I [ SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL NO. DIO 9.001 Mr. Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production LLC P.O. Box 1949 Kenai, AK 99611 Re: Mechanical Integrity Test Time Interval Revision DIO 9 — Kenai Unit 11 -17 (1811760) Dear Mr. Skiba: Marathon submitted an Application for Sundry Approvals (Form 10 -403) dated April 04, 2011 requesting the 1 -year Mechanical Integrity Test (MIT) interval currently in place for the subject well be changed to the standard 4 -year test interval contained in 20 AAC 25.252 (d). The standard 4 -year test interval is specified in Rule 2 of DIO 9; however a 1 -year test interval has been in place since tubing by inner annulus communication (TxIA) was suspected in 1998. Since the MIT interval is set forth in a Commission order, Marathon's request cannot be granted via Sundry Approval. The Commission will treat the request as an application for administrative approval under Rule 7 of DIO 9. Marathon's request to change the MIT interval is GRANTED in part, however the specified test interval will be 2 years. The request is granted based upon the MIT records for this well; a 2 -year interval is specified so that the well may be a readily available back -up for slurry injector KU 12 -17 (2080890) located on the same pad. In addition, the Commission has revised the text of Rules 2 and 3 to conform to the Commission's current integrity requirements. Now therefore, as provided by Rule 4 of DIO 9, Rules 2 and 3 are hereby revised as follows: RULE 2: Demonstration of Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, and before returning a well to service following a workover affecting mechanical integrity. After injection is commenced for the first time in a well, when injection conditions (temperature, pressure, rate, etc.) have stabilized, a Commission - witnessed MIT must be performed. Subsequent tests must be performed at least once every two years. The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1,500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows DIO 9.001 • • July 7, 2011 Page 2 of 2 stabilizing pressure and does not change more than 10 percent during a 30 minute period. Results of mechanical integrity tests must be readily available for Commission inspection. RULE 3: Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by the injection rate, an operating pressure observation, a test, a survey, a log, or any other evidence, the operator shall immediately notify the Commission, obtain Commission approval to continue injection and submit a plan of corrective action on Form 10 -403 for Commission approval. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating any well integrity failure or lack of injection zone isolation. Except as otherwise specifically modified herein, the statutes and regulations of the Commissio as well as the provisions of DIO 9, remain in full force and effect. faits ha 0/4 41 105/11, DONE at Anchorage, Alaska and dated July , 20 i • tri OTAKed 4 r I _ , -rte L�.4L"_ 1 �.711nyi�: Daniel T. Se. ount, Jr. t . Norman athy . Foerster Chair Co ■ . ioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may 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. • • Fisher, Samantha J (DOA) From: Fisher, Samantha J (DOA) Sent: Thursday, July 07, 2011 1:49 PM To: 'Aaron Gluzman'; 'Ben Greene'; Bruno, Jeff J (PCO); 'CA Underwood'; 'Dale Hoffman'; 'David Lenig'; 'Donna Vukich; 'Elizabeth Bluemink'; 'Eric Lidji'; 'Gary Orr; Heusser, Heather A (DNR); 'Jason Bergerson'; 'Joe Longo'; King, Kathleen J (DNR); 'Lars Coates'; 'Lois Epstein'; 'Marc Kuck'; 'Marie Steele'; 'Mary Aschoff; 'Matt Gill'; 'Maurizio Grandi'; Ostrovsky, Larry Z (DNR); 'Patricia Bettis'; 'Richard Garrard'; 'Ryan Daniel'; 'Sandra Lemke'; 'Talib Syed'; 'Wayne Wooster'; 'Wendy Wolif; 'William Van Dyke'; '( michael .j.nelson @conocophillips.com)'; '(Von.L .Hutchins @conocophillips.com)'; 'AKDCWeiilntegrityCoordinator; 'Alan Dennis'; 'alaska @petrocalc.com'; 'Anna Raff; 'Barbara F Fullmer; 'bbritch'; 'Becky Bohrer; 'Bill Penrose'; 'Bill Walker'; 'Bowen Roberts'; 'Brady, Jerry L'; 'Brandon Gagnon'; ' Brandow, Cande (ASRC Energy Services)'; 'Brian Havelock'; 'Bruce Webb'; 'Chris Gay'; 'Cliff Posey'; 'Crandall, Krissell'; 'D Lawrence'; 'dapa'; 'Daryl J. Kleppin'; 'Dave Matthews'; 'David Boelens; 'David House'; 'David Scott'; 'David Steingreaber'; 'ddonkel @cfl.rr.com'; 'Dennis Steffy'; 'Elowe, Kristin'; 'Erika Denman'; 'eyancy'; 'Francis S. Sommer; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin; 'Gary Schultz (gary.schultz @alaska.gov)'; 'ghammons'; 'Gordon Pospisil'; 'Gorney, David L.'; 'Greg Duggin'; 'Gregg Nady'; 'gspfoff; 'Harry Engel'; 'Jdarlington (jarlington @gmail.com)'; 'Jeanne McPherren'; 'Jeff Jones'; 'Jeffery B. Jones (jeff.jones @alaska.gov)'; 'Jerry McCutcheon'; 'Jill Womack'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John Katz (john.katz @alaska.gov); 'John S. Haworth'; 'John Spain'; 'John Tower'; 'Jon Goltz'; 'Judy Stanek'; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; 'Kelly Sperback'; 'Kim Cunningham'; 'Larry Ostrovsky'; 'Laura Silliphant (laura.gregersen @ alaska.gov)'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley (mark.hanley @anadarko.com); 'Mark Kovac'; 'Mark P. Worcester; 'Marguerite kremer (meg.kremer @alaska.gov)'; 'Michael Dammeyer'; 'Michael Jacobs'; 'Mike Bill'; 'Mike Mason'; 'Mike) Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'nelson'; 'Nick W. Glover'; 'NSK Problem Well Supv'; 'Patty Alfaro'; 'Paul Decker (paul.decker @alaska.gov); 'Paul Figel'; 'PORHOLA, STAN T'; 'Randall Kanady'; 'Randy L. Skillern'; 'Rena Delbridge'; 'Renan Yanish'; ' rob.g.dragnich @exxonmobil.com'; 'Robert Brelsford'; 'Robert Campbell'; 'Rudy Brueggeman'; 'Ryan Tunseth'; 'Scott Cranswick; 'Scott Griffith'; 'Shannon Donnelly'; 'Sharmaine Copeland'; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); 'Sondra Stewman'; 'Steve Lambert'; 'Steve Moothart (steve.moothart@alaska.gov)'; 'Steven R. Rossberg'; 'Suzanne Gibson'; 'tablerk'; 'Tamera Sheffield'; Taylor, Cammy 0 (DNR); 'Temple Davidson'; 'Teresa Imm; 'Terrie Hubble'; 'Thor Cutler; 'Tina Grovier; 'Todd Durkee'; 'Tony Hopfinger'; 'trmjrl ; 'Vicki Irwin'; 'Walter Featherly; 'Will Chinn'; Williamson, Mary J (DNR); 'Yereth Rosen'; Aubert, Winton G (DOA) (winton.aubert@alaska.gov); Ballantine, Tab A (LAW); Brooks, Phoebe L (DOA) (phoebe.brooks @alaska.gov); Colombie, Jody J (DOA) (jody.colombie @alaska.gov); Crisp, John H (DOA) (john.crisp @alaska.gov); Davies, Stephen F (DOA) (steve.davies @alaska.gov); Foerster, Catherine P (DOA) (cathy.foerster @ alaska.gov); Grimaldi, Louis R (DOA) (Iou.grimaldi @alaska.gov); Herrera, Matt F (DOA); Johnson, Elaine M (DOA) (eiaine.johnson @ alaska.gov); Jones, Jeffery B (DOA) (jeff.jones @alaska.gov); Laasch, Linda K (DOA) (Iinda.Iaasch @alaska.gov); Maunder, Thomas E (DOA) (tom. maunder @alaska.gov); McIver, Bren (DOA) (bren.mciver @alaska.gov); McMains, Stephen E (DOA) (steve.mcmains @alaska.gov); Mumm, Joseph (DOA sponsored); Noble, Robert C (DOA) (bob.noble @alaska.gov); Norman, John K (DOA) (john.norman @alaska.gov); Okland, Howard D (DOA) (howard.okland @alaska.gov); Paladijczuk, Tracie L (DOA) ( tracie.paladijczuk @alaska.gov); Pasqual, Maria (DOA) (maria.pasquai @alaska.gov); Regg, James B (DOA) (jim.regg @alaska.gov); Roby, David S (DOA) (dave.roby @alaska.gov); Saltmarsh, Arthur C (DOA) (art.saitmarsh @alaska.gov); Scheve, Charles M (DOA) (chuck.scheve @alaska.gov); Schwartz, Guy L (DOA) (guy.schwartz @alaska.gov); Seamount, Dan T (DOA) (dan.seamount @alaska.gov) Subject: dio9 -001 Kenai Unit Attachments: dio9- 001.pdf Samantha Fisher, Executive Secretary Alaska Oil and Gas Conservation Commission (907)793 -1223 1 • • Mary Jones David McCaleb XTO Energy, Inc. IHS Energy Group George Vaught, Jr. Cartography GEPS P.O. Box 13557 810 Houston Street, Ste 200 5333 Westheimer, Suite 100 Denver, CO 80201 -3557 Ft. Worth, TX 76102 -6298 Houston, TX 77056 Richard Neahring Jerry Hodgden NRG Associates Mark Wedman Hodgden Oil Company Halliburton President 408 18 Street 6900 Arctic Blvd. Golden, CO 80401 -2433 P.O. Box 1655 Anchorage, AK 99502 Colorado Springs, CO 80901 Bernie Karl CIRI Baker Oil Tools K &K Recycling Inc. Land Department 795 E. 94th a. P.O. Box 58055 P.O. Box 93330 Anchorage, AK 99515 -4295 Fairbanks, AK 99711 Anchorage, AK 99503 North Slope Borough Richard Wagner Gordon Severson Planning Department P.O. Box 60868 3201 Westmar Circle P.O. Box 69 Fairbanks, AK 99706 Anchorage, AK 99508 -4336 Barrow, AK 99723 Jack Hakkila Darwin Waldsmith James Gibbs P.O. Box 190083 P.O. Box 39309 P.O. Box 1597 Anchorage, AK 99519 Ninilchick, AK 99639 Soldotna, AK 99669 Kenai National Wildlife Refuge Penny Vadla Cliff Burglin Refuge Manager 399 West Riverview Avenue 319 Charles Street P.O. Box 2139 Soldotna, AK 99669 -7714 Fairbanks, AK 99701 Soldotna, AK 99669 -2139 .\ \4t6 \ \\ • 0 From: Dammeyer, Michael D. [mailto:mddammeyer@marathonoil.com] Sent: Thursday, April 15, 2010 12:44 PM To: Maunder, Thomas E (DOA) Cc: Ibele, Lyndon; Ostroot, James G. Subject: RE: Marathon Alaska Production LLC - Injection Well KU 11-17 (181-176) - Potential Communication Notification Tom, t) kQ ` Thanks for the reply; I understand you guys are busy and this is not the only thing on your plate We will make sure we watch the pressures when we try our first injection cycle, and shut everything down if we see anything amiss. Regarding the volume that was required to pressure up: that's an excellent question and I don't know the answer. The engineer who was observing the MIT is currently in the field; let me regroup with him and I'll let you know. Thanks again, Michael From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, April 15, 2010 12:24 PM To: Dammeyer, Michael D. Cc: Ibele, Lyndon Subject: RE: Marathon Alaska Production LLC - Injection Well KU 11-17 (181-176) - Potential Communication Notification Michael, Sorry I have been delayed getting back to you. It appears that it was operator's error that allowed the communication. Marathon's response to the potential communication was appropriate. It does appear appropriate for Marathon to return the well to operation. I only have one question, it is stated that 50 gallons of fluid was pumped into the annulus to achieve the test pressure. Do you have any information as to the volume split between what it might have taken to fill the annulus (fluid pack) and the volume actually employed to pressure up? I have not done the fluid compression calculation myself. Tom Maunder, PE AOGCC From: Dammeyer, Michael D.[mailto:mddammeyer@marathonoil.com] Sent: Thursday, April 15, 2010 11:48 AM To: Maunder, Thomas E (DOA) Cc: Ibele, Lyndon Subject: FW: Marathon Alaska Production LLC - Injection Well KU 11-17 - Potential Communication Notification Mr. Maunder, 0 0 I left another message on your voice mail earlier today (4/15/10) regarding the shut-in status of well KU 11-17; this email is a follow-up to that message. As discussed below, since we observed no pressure loss during our MIT on 4/9/10, and believe the original pressure loss from 4/2/10 was merely an operation error and not a mechanical failure, Marathon would like to run a single injection cycle to verify all is well, and if so to continue to use the well. Again, note that we are scheduled to have an AOGCC witnessed MIT in about a month on this well, and this will verify the MIT from the 9th. Your response is appreciated; note that Commission approval is required to continue injection after any irregular pressure observation on this well (KU 11-17 DIO Rule 3). Thank you, Michael From: Dammeyer, Michael D. Sent: Friday, April 09, 2010 4:00 PM To: 'tom.maunder@alaska.gov' Cc: Ibele, Lyndon Subject: FW: Marathon Alaska Production LLC - Injection Well KU 11-17 - Potential Communication Notification Mr. Maunder, This email is a follow up to the phone message I left for you this afternoon We believe we have found the problem on KU 11-17, which was a slightly open valve on the pressure transducer manifold. We performed performed an MIT on the annulus today after closing the valve, and it tested fine. The trend and notes from the test are below. We would like to run an injection cycle to verify everything is normal. If the pressures check out to your satisfaction, we would then like to return the well to injection (monitoring the pressures as normal),In the meantime, the well is SI and will remain so until we receive your reply. Note that we are scheduled to have an AOGCC witnessed MIT in about a month on this well, and this will verify the test we performed today as well. Thank you, Michael Michael Dammeyer Production Engineer 11 Marathon Alaska Production LLC 907-283-1333 (office) 907-394-8270 (cell) Test Notes: Upon arrival: outer annulus = 0 psi inner annulus = 300 psi long string = 0 psi • • ""00 00 0 "'N6elIM3IA1096sJJN%� OOOZ 0 !sd1 696SJIEI !sd'(uI SLI -IT IIaM 8I-Tb !sdM SLI II IIaM+ 911bV 0 ... '00:00:0 "'N6elIMMM096s4*a OOOZ 0 !sd 696SAJN !sd 'MUT-TTIIaM8T-Tb !sd(uI lLT II IIaM BIIbh`-!`� ""00:00:0 ...OP1IMMM096SAJ4� OOOZ 0 !sd 696SJIEN !sd 'MV/1-1T!I9MBT-Tb !sd[uI HLi Ii IIaM BIIbb '-T 0 ""00:00:0 "'N6elIM]IM096sJ36)%% OOOZ 0 !sd 6965AA !sd 6u!sQD Jaano LT - I I IIaM 8I-Tb �'�� ❑� aas ew!l ssaippv OI wnw!xeW wnw!wW sa!uN Jolo� JanaaS uo!a !J3sap _ aweN Gel OTOZ/6/b Wd 6T:£Z:£ aL�S tT Tti'1t4�Sit'��+""'s1�''aa ioi'�u i.• .: (_��€, SIITC o�5�d�`'•1 OTOZ/6/b OTOZ/6/f+ OTOZ/6/b OTOZ/6/b ... .�.�.�.-. ..0 ar 1 . IAu GT'Le]7T WA 6T:TT:7T OTOZ/6/b wv 6T:£Z:TT 0 C (00:8t,:Z0'sAep 0) !sd 0 !NV L lWtl b1;4V-L ULULtb/VJ !sd f ;WG 6T:6S=TT OTOZri6./6;. 0 i It took 50 gals of liquid to fill inner annulus and the pressure test went as follows: initial = 1490 psi 15 min = 1485 psi 30 min = 1482 psi The outer annulus and long string remained at 0 psi throughout the test. Pressure on the inner annulus was bled to 790 psi upon completion. Good test! 4j9.12010 11:59:19,AM 3 psi (4j9j2010 2:47:19 PM) 3 psi �Ltt 2000 2000 0 11:23:19 4M 12:11:19 PM 12:59:19 PM 1:47:19 P*9 4/912010 4j9j2010 4 9j2010 4 9j2010 k9firs%4;A4118_WeP_11_171-Otter—C&s [BesiP t - 0G ol: Tag Name Description Server Color Units Minimun E] 41-18 Well 11-17 Outer Casing Psi kgfrs969 psi ❑'� J A4118_Well_11_17A_InjPsi 41-18 Well 11-17A Inj. Psi kgfrs969 _ psi A4118_Well _II 17l_InjPsi 41-18 Well 11-171 Inj. Psi kgfrs969 psi " i A4118_Well_I1_175_InjPsi 41-18 Well 11-175 Inj, Psi Vgfrs969 psi f 0 • From: Dammeyer, Michael D. Sent: Monday, April 05, 2010 2:44 PM To: Maunder, Thomas E (DOA) Cc: Ibele, Lyndon; Skiba, Kevin I.; Walsh, Ken Subject: RE: Marathon Alaska Production LLC - Injection Well KU 11-17 - Potential Communication Notification Mr. Maunder, Your rapid response is appreciated. Below is the 90 day trend; we have four pressure monitoring points on this well (short string injection, long string injection, annulus, and outer casing). What we've found so far: - the current annulus/tubing pressures have been verified with physical gauges - the short string sudden drop in pressure from 70 to 40 psi on 4/2/10 was most likely merely a meter blowdown (it was blown down that day) I will keep you updated of anything else we find. In the meantime, the well will remain shut in. Please don't hesitate to call or email with any further questions. 2000 t414j2010 2:IM5 FM) 334 psi /, - -111 ....... OMI - - 459 psi(72 days,15:22:57) i 9 (�tiw � I - ------------- -- --- - - . _. -. _ r- __ - - _ ..._ - _............ '�1 311872010 1,lSjZ010 "2312010 2/10/2010 2/28/2010 1:IS: 37 PM 1:03:37 PM 12:51:37 PM 12:39:37 PM Tao Name Description Server F Color LMits Minimum Maximum I... Time Offset ❑ :-L A4118_KGF_ProdWater_Inj_FT 41-18 KGF W,W, Injection Flowrate KGFR5969 BPD 0 1000 ti,... MOM ❑ ,=.; A4118_PLC_KGF_Inj_Ttotal 41-18 KGF W.W. Inj. Today's Total KGFR5969 Barrels 0 1000 �... 0:00:00.... ❑� 1, A4118_Well_ll_17_Outer_Cas 41-18 Well 11-17 Outer Casing Psi KGFR5969 psi 0 2000 �... 0:00:00.... A4118_Well_li_17A_InjPsi 41-18 Well 11-17A Inj. Psi KGFR5969 psi 0 2000 ... 0:00:00.... • ,l A4118_Well_l 1_17L_InjPsi 41-18 Well I1-17L Inj. Psi KGFR5969 psi 0 2000 0 00:00.... 0 , A4118_Well_l 1_175_InjPsi 41-18 Well 11-175 Inj. Psi KGFR5969 psi 0 2000 ... 0:00:00.... 1:27:37 PM 4 /2010 1:15:37 PM 0 0 0 i From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, April 05, 2010 1:04 PM To: Dammeyer, Michael D. Cc: Ibele, Lyndon Subject: RE: Marathon Alaska Production LLC - Injection Well KU 11-17 - Potential Communication Notification Thanks Michael. Was there any active injection occurring when the annulus pressure loss was noted? Would you please provide a pressure plot that includes the pressures (injection tubing, 9- 5/8" annulus, others?) monitored on the well for the last 90 days? This is the standard request made when an operator reports a suspected pressure integrity loss. Shutting in the well is the appropriate response. I look forward to your reply. Call or message with any questions. Tom Maunder, PE AOGCC From: Dammeyer, Michael D. [mailto:mddammeyer@marathonoil.com] Sent: Monday, April 05, 2010 12:52 PM To: Maunder, Thomas E (DOA) Cc: Ibele, Lyndon Subject: Marathon Alaska Production LLC - Injection Well KU 11-17 - Potential Communication Notification Mr. Maunder, I called Jim Regg today regarding a potential communication to the annulus on injection well KU 11-17 (the pressure change was noticed on 4/2/10; the DIO for this well requires Commission notification on the first working day following the observation). Mr. Regg requested I send the details to you. KU 11-17 has dual 3.5" strings with a 9-5/8" annulus; we inject through the long -string 3-1/2" tubing. The annulus has been pressured to around 800 psi for monitoring, and has held steady in the past. Below is the annulus pressure trend (0 - 1000 psi scale) which fell rapidly to —320 psi. This well will remain shut in while we investigate. The long string tubing pressure is currently 160 psi and falling. We have not yet investigated for measurement error, but will do so. Please email or call with any questions, Michael Dammeyer Production Engineer II Marathon Alaska Production LLC 907-283-1333 (office) 907-394-8270 (cell) E 1 6- ~15 Marathon & commercial disposal ugh G&I facility Maunder, Thomas E (DOA) From: Stebbins, Tiffany A. [tastebbins@marathonoil.com] Sent: Tuesday, March 09, 2010 9:27 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: RE: Marathon & commercial disposal through G&I facility Tom, • Page 1 of 2 ~~ ~~si-i~~ Thanks for responding to the subject. If we do begin third party disposal, I will add a line item to capture the volumes on our annual DIO reporting. Regulatory Compliance Representative Marathon Oil Corporation Phone 907-565-3043 Ce11907-529-0522 Fax 907-565-3076 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, March 08, 2010 2:03 PM To: Stebbins, Tiffany A. Cc: Regg, James B (DOA) Subject: RE: Marathon & commercial disposal through G&I facility Tiffany, Commission Disposal Injection Orders (DIOs) authorize the Operator to dispose of Class II waste. We have not made any distinction regarding whether the injected waste is solely produced by the Operator or results from some third party's well operations. If third party waste is accepted, it is incumbent on Marathon to be satisfied that the waste is indeed Class II and meets the requirements of the DIO. In your annual report it may be appropriate to have a third party line item where such volumes can be listed. Call or message with any questions. Tom Maunder, PE AOGCC From: Regg, James B (DOA) Sent: Monday, March 08, 2010 11:45 AM To: Maunder, Thomas E (DOA) Subject: FW: Marathon & commercial disposal through G&I facility Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 3/9/2010 Marathon & commercial disposal ugh G&I facility ~ Page 2 of 2 907-793-1236 From: Stebbins, Tiffany A. [mailto:tastebbins@marathonoil.com] Sent: Monday, March 08, 2010 11:00 AM To: Regg, James B (DOA) Subject: Marathon & commercial disposal through G&I facility Hi Jim, We are considering commercial disposal. Would we need to convert our current disposal permit to a commercial disposal permit even if we intend to only dispose of approved Class II exempt wastes. Thanks, C'JtirJr~"' "J V ~,$~,~ Regulatory Compliance Representative Marathon Oil Corporation Phone 907-565-3043 Ce11907-529-0522 Fax 907-565-3076 3/9/2010 X14 i / :k .J ..5,. . ~ . t ,• f% 7 4 1 S ;-' c • t • Martamon ~ ,~, ri =1 -~~, .. x#13 • • ~ .,jai ~ 1 • r l• ~ i ~ ~ ~ s ~ :v 1 ~ -`- 7 i ~ ~.~' ~ j ~ ~ ;~ ~ , ~ ~~' ~ ~ ~ a ~ ®~°+~ ~'' FRANK H. MURKOWSKl, GOVERNOR ~.,,.._,...J ~, o, ~:,~..~ vis[1~7~ OIL A1~TD GAS ~ 333 W. 7'" AVENUE, SUITE 100 COI~TSERQATIOI~T COM)rIISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ' FAX (907) 276-7542 September 27, 2004 Proposals to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells The Alaska Oil and Gas Conservation Commission ("Commission"), on its own motion, proposes to amend the rules addressing mechanical integrity of wells in all existing area injection orders, storage injection orders, enhanced recovery injection orders, and disposal injection orders. There are numerous different versions of wording used for each of the rules that create confusion and inconsistent implementation of well integrity requirements for injection wells when pressure communication or leakage is indicated. In several injection orders, there are no rules addressing requirements for notification and well disposition when a well integrity failure is identified. Wording used for the administrative approval rule in injection orders is similarly inconsistent. The Commission proposes these three rules as replacements in all injection orders: Demonstration of Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and before returning a well to service following a workover affecting mechanical integrity. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30 minute period. The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval. The operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation. • • Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. The following table identifies the specific rules affected by the rewrite. Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Integrity" Confinement" Area Injection Orders AIO 1 -Duck Island Unit 6 7 9 AIO 2B - Kuparuk River Unit; Kuparuk River, Tabasco, Ugnu, West Sak 6 ~ 9 Fields AIO 3 -Prudhoe Bay Unit; Western Operatin Area 6 ~ 9 AIO 4C -Prudhoe Bay Unit; Eastern Operating Area 6 ~ 9 AIO 5 -Trading Bay Unit; McArthur River Field 6 6 9 AIO 6 -Granite Point Field; Northern Portion 6 ~ 9 AIO 7 -Middle Ground Shoal; Northern Portion 6 ~ 9 AIO 8 -Middle Ground Shoal; Southern Portion 6 ~ 9 AIO 9 -Middle Ground Shoal; Central Portion 6 ~ 9 AIO l OB -Milne Point Unit; Schrader Bluff, Sag River, 4 5 g Ku aruk River Pools AIO 11 -Granite Point Field; Southern Portion ~ 6 8 AIO 12 -Trading Bay Field; Southern Portion 5 6 8 AIO 13A -Swanson River Unit 6 ~ 9 AIO 14A -Prudhoe Bay Unit; Niakuk Oil Pool 4 5 8 AIO 15 -West McArthur 5 6 9 • • Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Integrity" Confinement" River Unit AIO 16 - Kuparuk River Unit; Tarn Oil Pool 6 7 10 AIO 17 - Badami Unit 5 6 g AIO 18A -Colville River Unit; Al ine Oil Pool 6 7 11 AIO 19 -Duck Island Unit; Eider Oil Pool 5 6 9 AIO 20 -Prudhoe Bay Unit; Midni ht Sun Oil Pool 5 6 9 AIO 21 - Kuparuk River Unit; Meltwater Oil Pool 4 No rule 6 AIO 22C -Prudhoe Bay Unit; Aurora Oil Pool 5 No rule 8 AIO 23 - Northstar Unit 5 6 9 AIO 24 -Prudhoe Bay Unit; Borealis Oil Pool 5 No rule 9 AIO 25 -Prudhoe Bay Unit; Polaris Oil Pool 6 g 13 AIO 26 -Prudhoe Bay Unit; Orion Oil Pool 6 No rule 13 Dis osal Injection Orders DIO 1 -Kenai Unit; KU WD-1 No rule No rule No rule DIO 2 -Kenai Unit; KU 14- 4 No rule No rule No rule DIO 3 -Beluga River Gas Field; BR WD-1 No rule No rule No rule DIO 4 -Beaver Creek Unit; BC-2 No rule No rule No rule DIO 5 -Barrow Gas Field; South Barrow #5 No rule No rule No rule DIO 6 -Lewis River Gas Field; WD-1 No rule No rule 3 DIO 7 -West McArthur River Unit; WMRU D-1 2 3 5 DIO 8 -Beaver Creek Unit; BC-3 2 3 5 DIO 9 -Kenai Unit; KU 11- 17 2 3 4 DIO 10 -Granite Point Field; GP 44-11 2 3 5 • • Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Integrity" Confinement" DIO 11 -Kenai Unit; KU 24-7 2 3 4 DIO 12 - Badami Unit; WD- 1, WD-2 2 3 5 DIO 13 -North Trading Bay Unit; S-4 2 3 6 DIO 14 -Houston Gas Field; Well #3 2 3 5 DIO 15 -North Trading Bay Unit; S-5 2 3 Rule not numbered DIO 16 -West McArthur River Unit; WMRU 4D 2 3 5 DIO 17 -North Cook Inlet Unit; NCICT A-12 2 3 6 DIO 19 -Granite Point Field; W. Granite Point State 3 4 6 17587 #3 DIO 20 -Pioneer Unit; Well 1702-15DA WDW 3 4 6 DIO 21 - Flaxman Island; Alaska State A-2 3 4 7 DIO 22 -Redoubt Unit; RU D1 3 No rule 6 DIO 23 -Ivan River Unit; IRU 14-31 No rule No rule 6 DIO 24 - Nicolai Creek Unit; NCU #5 Order expired DIO 25 -Sterling Unit; SU 43-9 3 4 7 DIO 26 - Kustatan Field; KF 1 3 4 7 Stora a Injection Orders SIO 1 -Prudhoe Bay Unit, Point McIntyre Field #6 No rule No rule No rule SIO 2A-Swanson River Unit; KGSF # 1 2 No rule 6 SIO 3 -Swanson River Unit; KGSF #2 2 No rule 7 Enhanced Recove In'ection Orders EIO 1 -Prudhoe Bay Unit; Prudhoe Bay Field, Schrader No rule No rule 8 Bluff Formation Well V-105 LJ Affected Rules Injection Order "Demonstration of "Well Integrity "Administrative Mechanical Failure and Action" Inte ity" Confinement" EIO 2 -Redoubt Unit; RU-6 5 8 9 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FR'VI STATE OF ALASKA NOTICE TO PUBLISHER ADVERTISING ORDER NO. ADVERTISING INVOICE MUST BE IN TRIPLI( ATE SHOWING ADVERTISING ORDER NO., CERTIFIED AFFIDAVIT OF PUBLICATION PART 2 OF THIS FORM) WITH ATTACHED COPY OF w 0.02514016 N ORDER ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE SEE BG+TTOM FOR INVOICE ADDRESS F AOGCC AGENCY CONTACT DATE OF A.O. R 333 West 7`h Avenue, Suite 100 ° Anchorage AK 99501 PHONE Pc "` , 907-793-1221 DATES ADVERTISEMENT REQUIRED: o Journal of Commerce October 3, 2004 301 Arctic Slope Ave #3S0 O Anchorage AK 99S 1 S THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED (N ITS , ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: AFFIDAVIT OF PUBLICATION United States °f America REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST division. REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION ~' Before me th d i d t li h MUST BE SUBMITTED WITH THE INVOICE. , e un ers gne , a no ary pub c t is day personally appeared ATTACH PROOF OF PUBLICATION HERE. who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2004, and thereafter for consecutive days, the last publication appearing on the day of .2004, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This _ day of 2004, Notary public for state of My commission expires ,Public Notices . • Subject: Public Notices From: Jody Colombe <Jody_colombie@admin.state.ak.us> Date: Wed, 29 Sep 2004 13:01:04 -0800 To: undisclosed-recipients:; BCC: Cynthia B Meiver <hren mciver@admin.state.ak.us>, Angela ~~'ebb <ange_wehb@adnun.state.ak.us=. Robert E Mintz <robert_mintz~u;la~t.state.ak.us=, Chl-istine Hansen ~~c.hanse@iogec.state.okus?, Terrie Hubble <hubbletl~cL~bp.com>, Sondra Stewman <StewrnaSD@BP.cam>, Scott & Cammy Taylor <staylor~~r;alaska.net=>, stanekj <stanekj@unocal.cam>, ecolaw <ecolaw@trustees.org>'roseragsdale <roseragsdale@gci.net>, trrnjrl <trmjrl@aol.eorn>, jbriddle <jbriddle@rnarathonaal.com>, rockhill -~rockhill~c?aoga.org>, shaneg <shaneg@evergreengas.com> jdarlington <jdarlington@forestoit.com>, nelson <knelson@petrol~tunnews.corn>, cboddy <cboddy@usib~elli.com>, Mark Dalton <mark.daltan@hdrinc.com>, Shannon Dannelly <shannon.donrtelly@conocophillips.com>, "Mark P._ Worcester" <mark.p.worcester@conocophllips.com>, "Jerry G. Dethlefis" <ferryc.dethlefs@conocophilhps_com>, Bob <bob@inletkeeper.org>, ~dv <wdl-ra~,drir.state.ak.us>, tjr <tjr@dnr.state.ak.us~, bbritch <bbritch@alaska.net>, mjnelson <mjnclson(a:purvingertz.c;om>, Charles O'~onr~eil <charles_o'donnell@veco.com>, "RandyL. Skillerr~" <SkilleRL~cL.BP.corn>, "Debarah J. Jones" <JonesD6@BP.com>, "Paul. G. Hyatt" <hyattpg(cr~?,BP.com>, "Stc~ en R. Rassberg" <RossbeR5@BP.com>; Lois.<lois@inletkeeper.org>, Dan Bross <kuacnews(_c;kuac.org>, Gardon ' Pospisil <PospisG@BP.com>, "Francis S. Sommer" <SornmerFSr~r;BP.com=~, It~tikel Schultz <Mikel.Sch~tz@~P.eom>, "Nick W.'Glover" <GloverNW~c%BP.com>, "Daryl J. Kleppin" <KleppiDE~a BP.eom>, '~JanetD. Platt" <P1attJD@BP.corn>, "Rosanne ~til. Jacobsen" <JacobsRM@BP.eom>, ddonkel <ddonkel@cfl.rr.corn7, Collins 'Mount <colins_mount@revenue.state.ak.us>, mckay <mckay@gci.net==. Barbara F Fullmer <barbara.f.fullmer@conocaphillips.com>, bocastwf <bocastvvf~Ubp.com=>, Charles Barker <barker@usgs.gov>, daug~schuItze ~doug_schultze@xtoenerg} .vom>, (-Dank Alford <hankalford@exxonmabil.corn>, Mark Kovac <yesnolCgci.net==, gspfoff <gspfoff@urorapower.com>, GreggNady<gregg.nady~-shell.com>, Fred Steecz <fred.steece@state.sd.us>, rcrotty <rcratty~eh2mcom>, j~jones ° jejones~aaurorapo~~rer.com>, dapa <dapa@aIaskii.net--, _jroderiek <jroderiek@gci.net>, eyanc4 <eyanc,yc~i!seal-tite.net%, "Junes M Ruud" <fames.m.ruuclr,'c~conocophillips.com>, Brit. Lively <~mapalaska(c_ak.net=>, fah <jah@dnr.state.~k.us=, Kurt E Olson <kurt 'oison@legis.state.ak.us>, buonoje <liuonoje@b~,com>, Mark Hanley<mark hanley@anadarko.com>, Loren lernan <toren leman+agov.state.akus>, Julie Houle<julie_houle@dnr.state.ak.us>, John W Katz <jwkatz@sso.org>, Suzan J Hill <suzan_hill@dec.state.ak:us>, tablerk <tabler@unocal.carn==, Brady ~~ brady~uaaga.org>, Brian Havelock <he@dnr.state.ak.cts> bpopp <bp€3pp@orough.kenai_ak.us>, Jim «~ hite <jimwliite@atx.rr:com>, ,`JohnS. Haworth", <john.s.haworth~~r,~exxonmobiLcom> ,marry <marty(2rkindustrial.com>, ghammons <ghammons~aol.com==. rmctean <rmclean~cc?pc~bor.ala`~ka.net>, nkn~72(1tl ~mkm720t1(u?aol.com>, Brian Gillespie <ifbmg~uaa.alaska.e:lu ~, David L Boelens <dboelens+aaumrapi~wer.com>, Todd Durkee <TDCIRKEE@KMG.com>, Gary Schultz <gary schultzrccdnr.state.ak.us>, ~~''"a~mv Ranvier. <RANCIER@petro-canaci~.ca>, Bill Miller <Bill_1Vfillc@~aoalaska.com>. Brandon Gagnon... <bgagnon@brenaiaw.corn>, Paul Winslow <pmwinslol~ @forestoil.com>, Garry Cation <catrongr@bp.eom7, `Sharmaine Copeland <copelasv@bp.com>, Suzanne Allexan <saIlexan@helmanergy.vom>, Kristin Dirks <kristin_dirks(~i~dnr.state.ak.us>. Ka~mell Zeman <kj~emanr~i.marathonoil.com>, John Tawer<John.Tower(a;eia.doe.gov>, Bill. Fowler <Bill_Fowler@anadarko.COM> Vaughn Swartz <vaughn.s~~~artz~~L'rbccm.com>, Scott Crans~vick 1 of 2 9/29(2004 1:10 PM Public Notices <scatt.crarrswick@mms.gov>, Brad McKim <mckimbs@BP.com> Please find the attached Notice and Attachment far the proposed amendment of .underground injection orders and the Public Notice Happy Valley #IQ. Jody Colombie Content-Type: applicatian/msword iNTechanical Integrity proposal.doc' Content-Encoding: base64 I Content-Type.: applicaton/msward Mechanical Integrity of Wells Natice.doc Content-Encoding: base64 Content-Type: application/msw-ord HappyL alleyl0_HearingNotice.doc Content-Encoding: base64 2 of 2 9/29!2004 1:10 PM ,Public Notice • . Subject: Public Notice From: Jody Colombie <jody colombie@admin.state.ak.us> Date: Wed, 29 Sep 2004 12:.55:26 -U800 To:-legal@alaskajournal,com Please publish the attached Notice on October 3, 2004. Thank you. Jody Colombie Content-Type: application/msword Mechanical Integrity of Wells Notice.doc Content-Encoding: base64 _ __ __ _ __ __ _ ___ _ _ .__ Content-Type: application/msword '' 'iiAd Order form.doc Content-Encoding: base64 1 of 1 9/29/2004 1:10 PM Crtgo Petroleum Corporation Mary Jones David McCaleb PO Box 3758 XTO Energy, Inc. IHS Energy Group Tulsa, OK 74136 Cartography GEPS 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 Ft. Worth, TX 76102-6298 Houston, TX 77056 Kelly Valadez Robert Gravely George Vaught, Jr. Tesoro Refining and Marketing Co. 7681 South Kit Carson Drive PO Box 13557 Supply & Distribution Littleton, CO 80122 Denver, CO 80201-3557 300 Concord Plaza Drive San Antonio, TX 78216 Jerry Hodgden Richard Neahring John Levorsen Hodgden Oil Company NRG Associates 200 North 3rd Street, #1202 408 18th Street President Boise, ID 83702 Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Kay Munger Samuel Van Vactor Michael Parks Munger Oil Information Service, Inc Economic Insight Inc. Marple's Business Newsletter PO Box 45738 3004 SW First Ave. 117 West Mercer St, Ste 200 Los Angeles, CA 90045-0738 Portland, OR 97201 Seattle, WA 98119-3960 Mark Wedman Schlumberger David Cusato Halliburton Drilling and Measurements 200 West 34th PMB 411 6900 Arctic Blvd. 2525 Gambell Street #400 Anchorage, AK 99503 Anchorage, AK 99502 Anchorage, AK 99503 Baker Oil Tools Ciri Jill Schneider 4730 Business Park Blvd., #44 Land Department US Geological Survey Anchorage, AK 99503 PO Box 93330 4200 University Dr. Anchorage, AK 99503 Anchorage, AK 99508 Gordon Severson Jack Hakkila Darwin Waldsmith 3201 Westmar Cr. PO Box 190083 PO Box 39309 Anchorage, AK 99508-4336 Anchorage, AK 99519 Ninilchick, AK 99639 James Gibbs Kenai National Wildlife Refuge Penny Vadla PO Box 1597 Refuge Manager 399 West Riverview Avenue Soldotna, AK 99669 PO Box 2139 Soldotna, AK 99669-7714 Soldotna, AK 99669-2139 Richard Wagner Cliff Burglin Bernie Karl PO Box 60868 PO Box 70131 K&K Recycling tnc. Fairbanks, AK 99706 Fairbanks, AK 99707 PO Box 58055 Fairbanks, AK 99711 Williams Thomas North Slope Borough Arctic Slope Regional Corporation PO Box 69 Land Department Barrow, AK 99723 PO Box 129 Barrow, AK 99723 [Fwd: Re: Consistent Wording for Injection~rs -Well Integrity Subj,eet [Fwd: Re: Consi tent Warding for Injection Orders - From John Norman <john_norman@admin.state.ak.us> Dater Fri, O1 Oct 2004 11:09:26 -0800 To: Jody J Colombie <jody_eolombie cc~admin.state.ak.us> more Well Integrity (Revised}] ------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders -Well Integrity (Revised) Date:Wed, 25 Aug 2004 16:49:40 -0800 From:Rob Mintz <robert mintz(a~law.state.ak.us> To:jim reggnu,admin.state.ak.us CC:dan seamount(r,~,admin.state.ak.us, john norman(u~admin.state.ak.us Jim, looks good, but I still think maybe it would be good to include the following sentence or something like it in the well integrity and confinement rule: "The operator shall shut in the well if so directed by the Commission." My thinking is that otherwise, an operator might argue that the Commission can only require the well to be shut in by going through an enforcement action, issuing an order after notice and opportunity for hearing, or meeting the strict requirements for an emergency order under the regulations. The proposed language makes clear that it is a condition of the authorization to inject, that the operator must shut in the well if directed by the Commission after a notification of loss of integrity, etc. »> James Regg <jim regg(c%admin.state.ak.us> 8/25/2004 3:15:06 PM »> Rob -Thanks for the review; here's a redraft after considering your comments. I have accepted most of the suggested edits.; also attached is response to questions you pose (responses are embedded in the comments, using brackets [JBR - ...] to set apart from your questions). Jim Regg Rob Mintz wrote: Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg <jim reQa(~admin.state.ak.us> 8/17/2004 4:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing 1 of 2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injectioners -Well Integrity ... - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Weil Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage}; - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and ail casing annuli}; this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions - adopts "Administrative Actions" title (earlier rules used "Administrative RelieF'); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu of terms like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDWs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. Norman <John Norman(a~admin.state.us> Commissioner Alaska Oil & Gas Conservation Commission 2 of 2 '~ 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injection ~s -Well Integrity ... • Subject: [Fwd: Res Consistent Wording for Injection Orders -Well Integrity (Revised)] From: John. Norman <john_norman@admin.state:ak.us> Date: Fri, O1 Oct 2004 11:08:55 -0800 To: 3ody J Colombie <jo@colombie@adminatate.ak.us> please print all and put in file for me to review just prior to hearing on these amendments. thanx ------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders -Well Integrity (Revised) Date:Thu, 19 Aug 2004 15:46:31 -0800 From:Rob Mintz <robert mintz(a,law.state.ak.us> To:dan seamount(a~admin.state.ak.us, jim reggnaadmin.state.ak.us, john normannaadmin.state.ak.us Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg <jim re~g(d~admin.state.ak.us> 8/17/2004 4:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions 1 of 2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injection~rs -Well Integrity ... ~ ' - adopts "Administrative Actions" title (earlier rules used "Administrative Relief'); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu of terms like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDWs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. Norman <John Norman(a~admin.state.us> '.:. !I Commissioner Alaska Oil & Gas Conservation Commission Content-Type: application/msword .....Injection Order language - questions.doc' Content-Encoding: base64 _ _ __ _ _ _ __ Content-Type: application/msword 'Injection Orders language edits.doc Content-Encoding: base64 _. __ 2 of 2 10/2/2004 4:07 PM • • Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, after a workover affecting mechanical integrity, and at least once every 4 years while actively injecting. For slurry injection wells, the tubing/casing annulus must be tested for mechanical integrity every 2 years. The MIT surface pressure must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, must show stabilizing pressure and may not change more than 10°lo during a 30 minute period. Any alternate means of demonstrating mechanical integrity must be approved by the Commission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement The tubing, casing and packer of an injection well must demonstrate integrity during operation. The operator must immediately notify the Commission and submit a plan of corrective action on Form 10-403 for Commission approval whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, or log. If there is no threat to freshwater, injection may continue until the Commission requires the well to be shut in or secured. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. • • Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter {except at least once every twig nears in the case of a slurry inf ection well), and. before returning a t~•ell to sen~ice. following a workover affecting mechanical integrity, .r a ,.* , -,~.,,:,~ ` ,,. ,, ,,,,,.. .r ~ ~: .+:,. ~ .+~ ~,,,. ~,,..,.<, CLLECl LLL 1~ ~ ,11.1VV uY~VLEy !' yVCLl ~) ,Y lltt S,. LC~r tr v. ~, o:' L;nless an alternate means is approved by the Commission mechanical integrity must be demonstrated by a tubing pressure test using a ~ ?~~surface pressure c~fnb~ 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, t11at m~~shows stabilizing pressure that does~ndy not change more than 10°=~ percent during a 30 minute period. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Inte rite Failure and Confinement Except as othen~;•iseprovided in this rule Tthe tubing, casing and packer of an injection well must c~emr~~~te-maintain integrity during operation. ~ti'henever anY~ressure communication, leakage or lack of infection zon~_solation is indicated by infection rate. operating pressure obsen~ation, test, survov log, or other evidence tThe operator ~r~~shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval. ~~ ~ .. , a~,j~,,+' ~+ ~, +~ ~ ~,.~r .~. „+: +,r+ . ~ _ The operator shall shut in the rE~ '"> ,' well i.f so directed by the Commission. The of?orator shall shut in the ~vcll ~~;•ithout awaiting_a response from the Commission if continued operation would he unsafe or would threaten contamination of freshwater _ °Z___ __ _..__ .. _ _..._ .,..~ ...., _, _.. ~o„"'~`°°;"„ ,• ", ; °" *' , " + ' '~ t ' :' ~ ~ Until~correctiye action is successfully completed, Aa monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. "[Fwd: Re: [Fwd: AOGCC Proposed WI Lang for Injectors)] Subject: [Fwd: Re: [Fwd: AOGCC Proposed WI Language for Injectors]] From: Winton Aubert <winton_aubert@admin.state.ak.us> Date: Thu, 28 Oct 2004 09:48':5.3 -080Q To: Jady J Colomhe <jody colombe@adtnin.state.ak.us> This is part of the record for the Nov. 4 hearing. WGA -------- Original Message -------- Subject: Re: [Fwd: AOGCC Proposed WI Language for Injectors] Date: Thu, 28 Oct 2004 09:41:55 -0800 From: James Regg <jim_regg@admin.state.ak.us> Organization: State of Alaska To: Winton Aubert <winton aubert@admin.state.ak.us> References: <41812422.8080604@admin.state.ak.us> These should be provided to Jody as part of public review record Jim Winton Aubert wrote: FYI. -------- Original Message -------- Subject: AOGCC Proposed WI Language for Injectors ~: Date: Tue, 19 Oct 2004 13:49:33 -0800 From: Engel, Harry R <Enge1HR@BP.com> To: winton aubert@admin.state.ak.us Winton... Here are the comments we discussed. Harry *From: * NSU, ADW Well Integrity Engineer *Sent: * Friday, October 15, 2004 10:43 PM *To: * Rossberg, R Steven; Engel, Harry R; Cismoski, Doug A; NSU, ADW Well Operations Supervisor *Cc: * Mielke, Robert L.; Reeves, Donald F; Dube, Anna T; NSU, ADW Well Integrity Engineer *Subject: * AOGCC Proposed WI Language for Injectors Hi Guys. John McMullen sent this to us, it's an order proposed by the AOGCC to replace the well integrity related language in the current Area Injection Orders. Listed below are comments, not sure who is coordinating getting these in front of Winton/Jim. Overall, looks okay from an Operations perspective. We do have a few comments, but could live with the current proposed language. Note the proposed public hearing date is November 4. The following language does not reflect what the slope AOGCC inspectors are currently requiring us to do: "The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and * before*_** 1 of 3 10/28/2004 11:09 AM [Fwd: Re: [Fwd: AOGCC Proposed WI Lan for Injectors]] return'.ng a well to service following a workover affecting mechanical integrity." After a workover, the slope AOGCC inspectors want the well warmed up and on stable injection, then we conduct the AOGCC witnessed MITIA. This language requires the AOGCC witnessed MITIA before starting injection, which we are doing on the rig after the tubing is run. Just trying to keep language consistent with the field practice. If "after" was substituted for "before", it would reflect current AOGCC practices. It would be helpful if the following language required reporting by the "next working day" rather than "immediately", due to weekends, holidays, etc. We like to confer with the APE and get a plan finalized, this may prevent us from doing all the investigating we like to do before talking with the AOGCC. "'Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, Iog, or other evidence, the operator shall_* immediately*_** notify the Commission" This section could use some help/wordsmithing: "A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation." Report content requirements are clear, but it's a little unclear what triggers a well to be included on this monthly report. Is it wells that have been reported to the AOGCC, are currently on-line and are going through the Administrative Action process? A proposed re-write would be: "All active injection wells with well integrity failure or lack of injection zone isolation shall have the following information reported monthly to the Commission: daily tubing and casing annuli pressures, daily injection rates." Requirements for the period between when a well failure is reported and when an administrative action is approved are unclear. This document states "the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403". If we don't plan to do any corrective action, but to pursue an AA, does a 10-403 need to be submitted? The AOGCC has stated they don't consider an AA as "corrective action". Let me know if you have any questions. Joe -----Original Message----- From: Kleppin, Daryl J Sent: Wednesday, September 29, 2004 1:37 PM To: Townsend, Monte A; Digert, Scott A; Denis, John R (ANC); Miller, Mike E; McMullen, John C Subject: FW: Public Notices FYI -----Original Message----- From: Jody Colombie ( mailto:j Sent: Wednesday, September 29, Subject: Public Notices dy colombieC~admin.state.ak.us 2004 1:01 PM Please find the attached Notice and Attachment for the proposed amendment of underground injection orders and the Public Notice Happy Valley #10. Jody Colombie «Mechanical Integrity proposal.ZIP» «Mechanical Integrity of Wells Notice.doc » 2 of 3 10/28/2004 11:09 AM .~.~z ~ - , 1 TONY KNOWLES, GOVERNOR gLASKA OIL AKD GAS COI~TSERVATIOI~T COMMISSIOIQ August 26, 1999 Chick Underwood HES Professional I Marathon Oil Company P.O. Box 196168 Anchorage, Alaska 99519-6168 Re: Requested Approval for Use of Defoaming Agent in Class II Injection Well KU 11-17 Dear Mr. Underwood: 3001PORCUPINE DRNE ANCHORAGE. ALASKA 99501-3192 PHONE: (9071 279-1433 FAX: (907}276-7542 ~~o~ This letter is in response to your August 24, 1999 request to add a defoaming agent to fluids injected into the KU 11-17 Class II disposal well on Pad 41-18 in the Kenai Gas Field. According to your letter, dated August 25, 1999, Marathon typically uses produced fluids for slurry makeup instead of fresh water. This practice provides a beneficial use for Class II fluids that would otherwise be considered waste and also minimizes the amount of produced fluid that must be injected into the Class II produced water disposal well WD-I. Marathon has encountered severe foaming problems during the current grind and. inject operations, due to a produced frac fluid with a high concentration of detergent. The foaming problems have severely limited injection rate and capability at the grind and inject site, causing the pumps and surface lines to cavitate from the entrained air. Marathon added water to the fluid in an attempt to curtail the foaming.: According to onsite personnel, adding fresh water only worsened the foaming problem. Marathon has furnished the Commission with three MSDS sheets for nonhazardous defoaming agents that you propose to use. According to personnel on location, approximately 1200 barrels of produced water are currently stored at Pad 41-18. The produced water is contained in several tanks, all with varying degrees of contamination from. the frac fluid additive. Marathon estimates that no more than 50 gallons of defoamer will be necessary to dispose of the contaminated fluids. The Commission grants approval to use any of the defoaming agents suggested, as necessary to operate the KU 11-17 well, until the detergent contaminated produced water currently stored at Pad 41-18 is disposed of. Chick Underwood August 26, 1999 page 2 Although we understand that Marathon has little alternati~-e to the use of the defoaming agent, we trust that Marathon will more thoroughly research products in the future and use frac fluids that require minimal treatment prior to disposal. Sincere Robert N. Christenson, P.E. Chairman ~ 1 ~! Alaskan ' r Domesti oduction ~~ S ~F M Marathon MARATHON Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 `g ~~~ August 25, 1999 _. ~>s ~ ~ ~,, , Ms. Wendy Mahan ,;~ ~x4~ ti:~.. t~ ~ : _ , d~t~:~~: Natural Resources Officer ~ `~~~~`~`~~` Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Class II Injection Well -Approval for Use of Defoaming Agents Dear Ms. Mahan, This letter is a request for a review of the information provided to you with the commissioners at the Alaska Oil and Gas Conservation Commission (AOGCC) during your field visit to Marathon facilities on the Kenai Peninsula on August 24, 1999. The discussion focused on the issue of foaming of the exempt fluids utilized for slurry make-up prior to injection into well KU 11-17, a permitted Class II disposal well located on Pad 41-18 at the Kenai Gas Field, and a request for approval to add a defoaming agent to control this problem. Marathon has stored and re-used exempt fluids from drilling and production since 1995 for a portion of the fluid used to create the slurry that has been injected into KU 11-17. This practice reduces the volume of fresh water used to develop the slurry, recycles the exempt fluids, and reduces the fluid volume injected into our other active disposal well, WD-1. During the current operation of the grind and injection equipment severe foaming of fluids has developed during the slurry make-up process with the introduction of the stored exempt production fluids. The foaming has severely constrained injection rates and the entrained air causes cavitation within the pumps and flow lines that can result in damage to the surface equipment and subsurface tubing. Additional volumes of fresh water have been added in an attempt to dilute the fluids that are being recycled and this has had no effect on the foaming problem. The solution to the problem is the addition of defoaming agents, a common practice during drilling and workover operations of wells. The use of defoaming agents in Class II injection wells is not explicitly stated and Marathon is requesting an expedited approval from the commissioners at the AOGCC for the use of anon-hazardous agent at this time to control the foaming problem. Once the fluids have been utilized and disposed the use of the defoaming agents would no longer be necessary. A subsidiary of USX Corporation Environmentally aware for the long run. Two products from Dowell/Schlumberger were provided to you yesterday for your review and I am also providing information on another product from MI/Swaco/DSR. Each of these products is non-hazardous and could be used without compromising the Class II well disposal practices. A prompt response from you on this issue is requested. I appreciated the opportunity to provide you with a tour of Marathon's production facilities and to observe the grind and injection operation on August 24, 1999. If you have any further questions please feel free to contact me at 564-6435. Sincerely, Charles A. Underwood, Jr. HES Professional I Attachments: Dowell/Schlumberger -MSDS - ANTIFOAM AGENT M45 Dowell/Schlumberger -MSDS - ANTIFOAM AGENT D47 MI/Swaco/DSR -MSDS - DEFOAM-X C: W. C. Barron w/o attachments R. J. Menzie, Jr. w/o attachments M. L. Susich w/o attachments File: 340.70 w/attachments e CODE: - .- Dowell DOWELL PRODUCT CODE M045 Effective Date: 04-March-1997 1. IDENTIFICATION OF THE SUBSTANCE/PRE_PARATION AND OF THE COMPANY/UNDERTAKING Identification of the substance or preparation: ANTIFOAM AGENT M45 , Company/undertaking identification: Dowell Safety/Environment -Worldwide 300 Schlumberger Drive Sugar Land, Texas 77478, USA Corporate Emergency Phone: Corporate Non-Emergency Phone: USA 1-281-595-3518 USA 1-281-285-8081 2. COMPOSITION/INFORMATION ON INGREDIENTS DIMETHYL SILOXANES AND SILICONES; CAS 63148-62-9; 5-10% WATER; CAS 7732-18-5; 60-100% 3. HAZARDS IDENTiF1CAT10N Emergency Overview Form: Liquid Color: Milk white Odor: Faint Main environmental hazards: None known. Main Physical Hazards Special Precautions: None. Physical Hazard: None. Main Health Hazards: HMIS RATING: Health 2 Flammability 1 Reactivity 0 May cause eye irritation. See Section 11 for a complete discussion of health hazards. 4. FIRST AID MEASURES Eye contact: Skin contact: Inhalation: Swallowing: Notes: 5. FIRE FIGHTING MEASURES Extinguishing media: M045 Effective Date: 04-March-1997 MATERIAL SAFETY DATA SHEET (Complies with USA OSHA 29 CFR 1910.1200 and ANSI Z 400.1} Immediately flush eyes with water for 15 minutes while holding eyelids open. Seek medical attention. Rinse with water. Remove to fresh air. Rinse mouth with water. Seek medical attention if irritation occurs. None. Water Fog, Alcohol Foam, C02, Dry Chemical, Water F1°~e tl off 4't DOWELL PRODUCT CODE: M045 Effective Date: 04-March-1997 Further Information: Wear protective fire fighting clothing and avoid breathing vapors. Use self-contained breathing apparatus in closed areas. Flash point: > 212°F Method: Tag closed cup Flammability (explosion limits in air): Lower: Not applicable Upper: Not applicable Autoflammability (auto-ignition temperature): Not determined Explosive properties (thermal decomposition temperature): Not determined NFPA Rating: Health 2 Flammability 1 Reactivity 0 Other: None Combustion products: see Section 10. 6. ACCIDENTAL RELEASE MEASURES After spillage/leakage: Contain with dikes. Put in steel or plastic drum. Flush residual with plenty of water. See Section 8 for protective equipment information. See Section 13 for disposal information. 7. HANDLING AND STORAGE Special Precautions: Avoid freezing. Freezing may destroy emulsion. Packaging requirements: High density polyethylene (HDPE) drum (DOT 34) or can. Ventilation: Provide ventilation to keep airborne concentrations below exposure limits. _ . 8. EXPOSURE CONTROLS/PERSONAL PROTECTION Respiratory protection: None normally needed. If dust or mist is generated use NIOSH approved respirator with dust and mist protection (color coded gray or 3M 8710). Eye protection: Chemical splash goggles. Hand protection: None required. Skin protection: Exposure Limit Guidelines (mg/m3) No components have established exposure limits. 9. PHYSICAL AND CHEMICAL PROPERTIES Form: Color: Odor: pH value: Boiling point: Pour point: Vapor pressure: Relative density (specific gravity): Bulk Density (solids): Solubility in water: Clean, body-covering clothing. Liquid Milk white Faint 6-8 212°F Not determined 4.0 kPa (68°F) 0.95-1.05 (68°F) Not applicable 900 g/1(68°F) Page 2 of 4 DOWELL PRODUCT CODE: M045 Effective Date: 04-March-1997 Viscosity: Not determined Relative Vapor Density (air-1): Not available Volatile: >80 Nature Polymer(Si) 10. STABILITY AND REACTIVITY Stability: Stable. Conditions to avoid: Not determined Materials to avoid: Oxidizers Hazardous Polymerization: Will not occur. Dust explosion hazard (solids): Not applicable. Special hazards: None. Hazardous decomposition products: Silicon oxide When heated strongly or burned, oxides of carbon and harmful organic chemical fumes are released. 11. TOXICOLOGICAL INFORMATION Eye contact: Irritant. May cause pain, redness, discomfort. Skin contact: No effect expected. Prolonged or repeated contact may cause mild irritation. Inhalation: No effect expected. Prolonged or repeated exposure may cause mild irritation. Ingestion: No effect expected. Swallowing large amounts may cause illness. Carcinogenicity: Not listed by IARC, USA NTP, or USA OSHA. Mutagenicity: Not known to cause heritable genetic damage. Teratogenicity: Not known to cause birth defects. Target organs which may be affected: None known. Sensitization: Not known to cause allergic reaction. Other: None. 12. ECOLOGICAL INFORMATION Information on product as a whole: Main environmental hazards: None known. Degradability: Not determined Fish Toxicity: Not determined Acute invertebrates toxicity: Not determined Growth Inhibition (algae): Not determined Other: None known. 13. DISPOSAL CONSIDERATIONS Product: May be incinerated (preferred) or injected in disposal well. Small amounts may be acceptable in sanitary sewer; check local regulations. Page 3 of 4 DOWELL PRODUCT CODE: M045 Effective Date: 04-March-1997 Container: Sell to approved drum reconditioner or render container unuseable by puncturing or crushing. Send to sanitary landfill unless prohibited by local regulations. USA EPA RCRA: None. 14. TRANSPORT INFORMATION ICC Tariff Classification Compound, Boiler Cleaning, Scale Removing, Liquid ICC Item Number: ICC Class: 55 LTL CERCLA RQ: Not established. Department of Transportation (DOT) Designation: Hazard Class: Shipping Name: DOT Label: Canadian Shipments Shipping Name: Label: Classification: Not Regulated Not Regulated Not Regulated Not Regulated Package Group: TL PIN: none 15. REGULATORY INFORMATION Notification/restrictions status: USA: All components of this material are an the USA TSCA inventory, or the components are exempt from inventory reporting. CANADA: All components of this material are on the Canada DSL, or the components are exempt from inventory reporting. This product contains no chemicals subject to the USEPA reporting requirements of SARA 313. The USEPA CERCLA Reportable Quantity (RQ) for this product as a whole is: Not established. Canadian WHMIS classification: D26 16. OTHER INFORMATION Sections affected by last revision: PHYSICAL AND CHEMICAL PROPERTIES "Mark of Schlumberger. The information herein is believed to be accurate and is presented in good faith; however, no warranties. or representations are made by Dowell regarding the accuracy or completeness of the information. Page 4 of 4 .~ CODE: D047 Effective Date: 2-September-1997 - • - MATERIAL SAFETY DATA SHEET Dowell (Complies with USA OSHA 29 CFR 1910.1200 and ANSI Z 400.1) DOWELL PRODUCT CODE: D047 Effective Date: 02-September-1997 1. IDENTIFICATION OF THE SUBSTANCE/PREPARATION AND OF THE COMPANY/UNDERTAKING Identification of the substance or preparation: ANTIFOAM AGENT D47 Company/undertaking identification: Dowell Safety/Environment -Worldwide 300 Schlumberger Drive Sugar Land, Texas 77478, USA Corporate Emergency Phone: USA 1-281-595-3518 Corporate Non-Emergency Phone: USA 1-281-285-8081 2. COMPOSITION/INFORMATION ON INGREDIENTS POLYPROPYLENE GLYCOL; CAS 25322-69-4; 60-100% 3. HAZARDS IDENTIFICATION Emergency Overview Form: Liquid Color: Colorless Odor. Faint Main environmental hazards: None known. Main Physical Hazards Special Precautions: None. Physical Hazard: None. Main Health Hazards: HMIS RATING: Health 1 Flammability 1 Reactivity 0 May be mildly irritating to eyes. See Section 11 for a complete discussion of health hazards. 4. FIRST AID MEASURES Eye contact: Skin contact: Inhalation: Swallowing: Notes: 5. FIRE FIGHTING MEASURES Extinguishing media: Further Information: Flush eyes with water for 5 minutes. Get medical attention if irritation occurs. Rinse with water. Remove to fresh air. Rinse mouth with water. Seek medical attention if irritation occurs. None. Water Fog, Alcohol Foam, C02, Dry Chemical Wear protective fire fighting clothing and avoid breathing vapors. Use self-contained breathing apparatus in closed areas. I~~ 11 off $ DOWELL PRODUCT CODE: Flash point: Method: D047 Effective Date: OZ-September-1997 365°F Pensky-Martens CC Flammability (explosion limits in air): Lower: Not determined Upper: Autoflammability (auto-ignition temperature): Explosive properties (thermal decomposition temperature): NFPA Rating: Health 1 Flammability 1 Reactivity 0 Other: None Combustion products: see Section 10. 6. ACCIDENTAL RELEASE MEASURES After spillage/leakage: Not determined Not determined Not determined Contain with dikes. Put in steel or plastic drum. Soak up residual on inert absorbant (sand). See Section 8 for protective equipment information. See Section 13 for disposal information. 7. HANDLING AND STORAGE Special Precautions: No special precautions required. Packaging requirements: Steel or high density polyethylene (HDPE) container. Ventilation: Provide ventilation to keep airborne concentrations below exposure limits. 8. EXPOSURE CONTROLS/PERSONAL PROTECTION Respiratory protection: None normally needed. If dust or mist is generated use NIOSH approved respirator with dust and mist protection (color coded gray or 3M 8710). Eye protection: Chemical splash goggles. Hand protection: None required. Skin protection: Clean, body-covering clothing. Exposure Limit Guidelines (mg/m3) No components have established exposure limits. 9. PHYSICAL AND CHEMICAL PROPERTIES Form: Color: Odor: pH value: Boiling point: Pour point: Vapor pressure: Relative density (specific gravity): Bulk Density (solids): Solubility in water: Viscosity: Relative Vapor Density (air-1): Volatile: Liquid Colorless Faint 8.5 (68°F) (at 100 g/I) Decomposes prior boiling point Not determined Not determined 1.0 (68°F) Not applicable Insoluble 980 mPa.s (68°F) >1 <1 Page 2 of 5 DOWELL PRODUCT CODE: D047 Nature 10. STABILITY AND REACTIVITY Stability: Conditions to avoid: Materials to avoid: Hazardous Polymerization: Dust explosion hazard (solids): Special hazards: Hazardous decomposition products: 11. TOXICOLOGICAL INFORMATION Eye contact: Skin contact: Inhalation: Ingestion: Carcinogenicity: Mutagenicity: Teratogenicity: Target organs which may be affected Sensitization: Other: 12. ECOLOGICAL INFORMATION Information on product as a whole: Main environmental hazards: Degradability: Fish Toxicity: Acute invertebrates toxicity: Growth Inhibition (algae): Other: 13. DISPOSAL CONSIDERATIONS Product: Container: USA EPA RCRA: 14. TRANSPORT INFORMATION Effective Date: Surtactant 02-September-1997 Stable. Not determined Acids Oxidizers Will not occur. Not applicable. None. When heated strongly or burned, oxides of carbon and harmful organic chemical fumes are released. Mildly irritating. No effect expected. Prolonged or repeated contact may cause mild irritation. No effect expected. Prolonged or repeated exposure may cause mild irritation. No effect expected. Swallowing large amounts may cause illness. LD50 (rats) > 15000 mg/kg Not listed by IARC, USA NTP, or USA OSHA. Not known to cause heritable genetic damage. Not known to cause birth defects. None known. Not known to cause allergic reaction. None. None known. Not biodegradable. BOD = 0.15 p/p; COD = 1.94 p/p Not determined Not determined Not determined None known. Ship via permitted waste hauler to permitted hazardous waste disposal facility for incineration (preferred) or disposal well injection of all liquids and landfifling of solids. Sell drum to an approved drum reconditioner or triple rinse, crush, and ship to sanitary landfill unless prohibited by local regulations. None. Page 3 of 5 ~. ~ , DOWELL PRODUCT CODE: D047 Effective Date ICC Tariff Classification Compound, Gas or Oil Well Drilling ICC Item Number: 138640 ICC Class: CERCLA RQ: Not established. Department of Transportation (DOT) Designation: Not Regulated Hazard Class: Not Regulated Shipping Name: Not Regulated DOT Label: 02-September-1997 50 LTL 35 TL Canadian Shipments Shipping Name: Not Regulated Label: Classification: Package Group: PIN: none 15. REGULATORY INFORMATION Notification/restrictions status: USA: All components of this material are on the USA TSCA inventory, or the components are exempt from inventory reporting. CANADA: All components of this material are on the Canada DSL, or the components are exempt from inventory reporting. This product contains no chemicals subject to the USEPA reporting requirements of SARA 313. The USEPA CERCLA Reportable Quantity (RQ) for this product as a whole is: Not established. 16. OTHER INFORMATION Sections affected by last revision: PHYSICAL AND CHEMICAL PROPERTIES *Mark of Schlumberger. The information herein is believed to be accurate and is presented in good faith; however, no warranties or representations are made by Dowell regarding the accuracy or completeness of the information. Page 4 of 5 AUu, 70. 19~ 9 3 : D4Pt49 ~. MI SWAt;O DSR -I I;RIr?.IiuU AIrASKA N0. 634 P, 1 ~° ;~' ~ ~ • • 721 W. First Ave Anchorage, AK 99501 (907) 274-55$4 Ta: ,lk: ~''S'/ ~ r~ Fax Number: l ~j ~j ID l~ ~ l ~~ Number of Pages including Caver: Date: ~p l7 From: -- -_. __..~..~ ~"'~' ~f//svS ,<0.2 D~`~~~ /' M-1 DIRECT PHONE LINE NUMBERS U_tJ$tairs FAX Craig Sei#aer Paul Hanson Tim Jphnson Christine Miner Bonnie Mitchell John Murphy Tvny Tykalslry _...j90y} 279-6729 (907) 2745051 5r. Area Manager (907) 274-5027 Tech Services Manager (907) 2745070 H$E Caordinatvr isala (907) 2745035 Accounts Payable (907) 2745025 Area Secretary (907? 274-5057 Project Engineer Manager (907) 2745011 Project Engineer Downstairs FAK (9071 274-5056 been Bryan (907) 274-5Q03 Sr. Tech Service Engineer Kristine Fenvvrck {907) 274-5016 lrnerrtpry Control Randy Graham (907) 274-5048 Distribution Man2rger Max Hobson {907) 2745048 Distribution Consultant Kenai OfFce FAX _ (9071778-5g9g John Flelden (907) 776-868D Worth Slope FAX 19071659-2292 SWACOliiSR DIRECT PHONE LINE NUMBERS SVI(AGO/L?SR FAX 907 274.6535 Susan Douglas (907) 274-5507 Admin. Assistant Cryde Treybig (907) 274-5541 Sales Manager Steve Simmons (907) 274-5533 Area Manager Bruce Spiffier {907) 2745519 Operations IGm Winttvus (l307) 2745037 Tech Service Sho FAX 907 349819 225 VII, 92"d Ave Office (907) 344765 North Sla a FAX 907 ty59-2891 l7ffice (24 hrs) (JV7) 65~J-2890 Dennis t3aker 6807) 659-2694 Jeff Berryhill {907) 656-2694 Mike Kish {907) 659-2694 ~U~J, ~G, 19'ti~~r ~;'~,Fi~M~-~i-I DRIVING AI,ASI(A ~ T1~~. 4~r, ~TERIAL' SAFETY OA~SNEET DEFOAM-X '!. +CHEMiCAL PROpUCTANp COMPANY iDENTiFiCA~70N TRlapE NAME: CFIEMIrwAL CLASS: AFPL.IfrATIUNS: EMERGENCY TELEP>•ONE: SUPPLI Eta: TELEPHONE: FA1(: coNTACT PERSON: I~I~ ClA1VI JC Surfactant. Oil wc]1 driliir~g lltud additive.l)el-p~mcr, 2S 1-561-160t~ Supplied b5' a Business tJ>aot oC M-I L.L.C. ' 1'.C1, Bax 42842, Hc-ttaton, Toxas 77242-2842 See cUVCr sheaf for local aupplicr. zA~-s~l•ISO9 zs1-561-7241) Sean Hoakirt 2. CC)MPOSiT1oN, INFORMATION ON INGREDIENTS INt'sR~Qi@I~IT NAME; CAS No.: CCINTEIVTS : EPA RQ: TPq: ~. wazARr~s rDENnFicATION EMERGENCY OVERYfEW: CA[.JxION! MAY CAU5E EYE, 5ICIN ANIa RE.-PIRATOi<i.Y TItgCT IRRITA'I'tUN, Aroid cotu~u;t with eyes, and utaUpt~g, Avoact t7realhing atr6utue prrJtluCt. Kcep coatiairua claeed_ Uwc with adct~tatc venlile~ou, Wash thoroclgttly alto handling, Thisproduct is e/on whilo ligsud lYo sigsti~tcant itnmedietc t>azanfs for comcrgcnny reapcrose persooaitcl arc ]umwn. I)iEoc end wntaia cplla. Kecp out of scwerys and waterwgys. ACUTE EFFECTS: INFIALA~'ION: May be inhaling to the rral$retgty tract if inhalcd 1NGE9i'rON: dt4ay cause p~etticdishesg, nauseaemd vamitittg itiugcatod. SKIN: May be irritating ro the sign. E1fES: May be irritating w the eyes. CHROMIC EFFECTS: CARCINOGENICITY: IA~G: Not Gated. G+SHA: Not rogutt;tod. N"f F. Nut listc~ Rt7UTE OF ENTRY; IrrtWiation. tilcin rurd/or eye ~~t, I/6 AUK, 20, 1~9~~' ~.L6PM'~ ~~-I DRIIJI,ING ALASKA N~. 6304 ~, 3~ TARGET t7RGAM$: • ~I~~' 9Ystat~,1 s. Slav. ~ cs, _.._ ._....... . ~B Y ~. FIRST AdQ MEASURES GENERAL: Ilcrsous Peking medical attention should Derry a copy of this lvLSDEi with Qtcan. IMNAIATI(7N: Move tIx exposed petvan to fresh air at once- NerCorm ariiGcial respiration if breathing Las stoppod_ Ciet medical attc:ntimr. IhIGESi1taN: Lkink a couple ofg]agae~.vater or mills. i7o NOT itlduce vomiting waterer ekntiatcd to do ~ by a physiciau. 1'~:ver give anything by aaaoutlr to an unconscious pCrson, Got mcdice! trtlealivn, SI(IN: Wash slra~t thoroughly with Soap sacl waicr. Remove cotri~ningh~d clogtittg. Get nuxlictil altentiou il'any clisaaatfort wnlimtes. EYES: Promptly woyh eyes w;tlh lots of wafer while lifling the eye lids. f:antinue to rinse for at least 15 rninules. fist medic,`9[ alteraflu~niCauy diswmfvrlwnr;nues. 5, FIRE FIGHTING MEASURES FLASH RoINT SFr; AUTO iGNITiON TEMP. (°l7: FLAMMABILITY LIMIT • LUWER(yo); FLAMMABILITY LIMIT - UPPER(ib): E,l(TiNGUIS~iING MEDIA: Carbon dioxide (C(YZ; ~39~Jr 1~Tli(]D: PNi Closed N/D N/D N/D ~, Dry chemicals. Foarn. Water spray, fog or mist. SPECIAL FI6tE FIGH711~G pROCEDUI~S: Wear positive-pressure, self~onteia>«l taeathing apparatus (SCIl,4) arul prote+cflve tiro fighting clouting (iucluding fin rt~~g ~et> coat, pants, buoy, and gloves), Ifpxrottc;Gve aquipniettt is no t available yr not used, ft$h! fire from a protected location or safe distance. uNl1SUAL FIRE. R EXPLOSIpN HAZARDS: No unusual trn or expl~ivn hazanla stvted. HAZARDOUS coMBUSTIOIV pROOUCTS: Iaif<'+tivg gascalvapoas/tumos. Oxides of: Carbon 6. ACCIDEIVT~OL RELEASE MEASURES PERSONAL PRECAUTIONS; Wear proper persaual protective ecluipmeut (ece MS1.7S Sccfiou S). SPILL CLEAN-fJP pROCEpURES: Absorb rn vermictilite, dry satrl or tartL srul placo inW ~xmlaittet~. Rinse area with wa~er.l~ike far alrcad of Largc7 spills Cvr later disposol_ lav not ~atwnlnnte charinagc or waterways. 7. HANDLING AND STORAGE HANDLING PREGAU'IiQNS; Vetatilalo wdd. av~idl+~lhittg vuiturs, Use t~laproved r<~iratur ifttir cwrtautiuatias is alwve.axcl>ttxl Ic;vcl. Wuu lltll protativc olniliiag for prolonged exposure and/or big6 conrelllrtltians. Fye wash and emergency shower must tre available at the wank place. 2/6 AUG. 20, 1999=~ 3~OBPivI"~ •..._hI-I -RII,L~I~~G ALASKA N0, X304 P, ~ STORAGE PRECAUTIONS' M Y..--- Store at moderate tetnpcrattaea is dry, wsalI vt~rGlated area. ICrcF iW original wntairtcr. 8, EXPOSURE CONTROLS, PEf'tSONAL PRDTECTION INGREDIENT NAME: I'rOt~~y ittgredicnts OSHA PEE.: ACGIH T~,V: OTHER: CAS Na: TWA: STEL: TWA: STEi.: TWA: STEL: UNITS: IS lU n~t/:tt3 lo-al dt15i INGREDIENT CQM MENT5: Ex{~asure 6Writs for Fsaticulstes Not ~ Classified ('I'NUC) apply to dust/nrtst/~rctsot of the pmpxietucy atgrcdients this product. PROTECTII/E EDUIPMENT: oeo~ I:NGINEEI~ING CONTROL: Use aPProP~ta etrginecring controls such aaa exhaust ventilation and pmaeess enclosure, to redw:c air~atatnination and keep worker cxposura below the applicable lurrits• VENTILATION: Supply naturoE or Wrcchauic~! vcntilaticq~t adequate to exhaust airbnnte product oral keep urgtoaures below llx applicable limits. RESPIRATORS: ICexpnaed W partiealateslacroaols~ Usc at lean! a NIOSXI-~pprovcd I~TyS halGrnesk diapvaabie or r~useable pnrticulatc respirut~r, Li work a~rriiortrncnts cdnnlairtbrg oil misVacr+osol use at Icay1 u IVIOSJ-I-eriprovad IxIS hall=mask dispnsable or retuuablc particulate reapitaior. If rxposcd tp etganio voporn; Use a 1`Q~H/MSI-IA-approved orgaWic vapor respirator. CCKOV: CCR u'11h rngmvc vapor cartridge. PROTECTIVE GLOVES: Chemical rcaiatant glows required For prnlangcd or rel~ratcd eotttect. Usc protective glovca made of: Lnpornx:ahlc n>stlcrial. Such as,Nrx>ptcne, trittile. polyethyleWC or PVC. EYE: pIZOTECI`ION: Waar ctsetnloal safety guBBla where aye exposure ie re~anaWy pmbnble. PROTECTEV~ CLOTHING: Wear appropriate olOthirrg ~ ptivcnt repeatai or prolonged s{ciu tw~xtact. HYGIENIC WORK PRACTICE5: Wash I>rompily with soap slat! water if skirt bex~tn~ cx-nlairtinatal. Clrmtga work clo0ring daily if there is ta,y possibility ofcontAttuualiou, 9. PHYSICAL AND CHEMICAL RROPERTIES AI'PEAIZANCEJPHYSICAI. STATE: CCILOR: oooR: SOLUBILITY DESCRIPTION: dENSIiYlSI'ECIF{CGRAV!TY (8fml~: VAPOR DENSITY (airs!): VAPOR PRESSURE; EVAPORATION RATt~t pN YALUt:, t)ILUTE.D SOLUTION: Litlttid. whirs. Mild (ar faint). !Wadable i!d water. U9 - l.0 1'EMPI;ItATURE (°l+); 68 N/l7 {1.U mmHg 'C~'MPP.RA'1't1RF. ('F): tis ld/1) KIs'F1~ ~LYCJr: 5.8 t::()riGENTRATION (%~VI): 14/0 316 AUG. cll, i9~G=~ G; G6PI~It .,_,~'?I-I DRiLLNG AI.A~KA NG, 630 P, G 10. STABILITY AND REACT1ViTY f STABILITY: Nam~ally stable CONpITIONS TO AVOID: Avoid heat HAZ,ARpOUS PpLYMERl7.l1TION: Will riot polymerize. POLYMERIZATION DESCRIP'YION: Not relevant, MATERIALS TO AVOID: Strong oxidi~rtg agents. HAZARDOUS DECOMPOSII'IOIV PROQUC'TS: Na specific haxerctot~ decomposition products noted. . 1 i. T~OXICOL,QGIC1IL fNFO1~MATION TO>(lC DO$@ _ LD 5t7: >SUDO rtlgJkg (Drat rat) TOXfCOLOGICAL INFaRMAT10N; No tvxicoIogioal dwa is available Cor this pdwliect. Taxicxlc-gical data givad show is for a major componeul. 12 ~COLOGNCAL tNFURMATItJN ACUTE Agt~A1p'IC TOXICITY: This product is approved for aye uadcr t>ae U,S. Envir~amttrial Pratectir~n r'I.~enoy (T.tiPA) Ragioii iX (California) Gencrai HI'DI;S Prarnii whic:tt regWalcs oLTeZore discharges of drilling t]uids. C:gt~[act M I's Ltvixoinncntat AtXairs Ikpartnx:nl Coa more information. I7tis prpc]uctpBSSCS the mysid shrimp toty tact required by the 1J.5, Ena7ronittcnlxl I'roteetianAgciicy (t~'A) Rcgiarr VI (Gulf uCMcuico) NPDES Perari 1, wlrich rcgulalos oiTsfroro disaherge aCdrilling tlaids, wheaA tcstrad in a startdssd drilling Duet, Coa1.'!~t M-I's $nvirbnmcnml A.ITairs i~~rt far more inlbmtalion. '13. O15P45AL IrON31D~RAT1t7NS WAS7f: MANAGEMENT: 'l7sis product does riOCvrcet the criteria of a haraadous waste if diseartlccl in its purchased form. Under RCRA, it is the ~aponsibitity of ll~e uscx of Ute product to dct4xmine+ al the lime of disposail, whether tlx; pradual nrocts RC'.RA criteria for l7rtzardou9 waste. Tlbs is because product uses,lrmsfe)rmations, mixtures, prooesscs„ etc, may rcaclcr the resultiaig materials hazardous, Ircnpty amtainerB retain residues. All labiolcd pre~utiona must bo observed, DISPOSAL METHODS: Recover and raclaittt or recycle, if pre~e4cat, Should this product bxanae s waste, dispuac of in a t+camittcrl iuduslria[ landGl-. C1LRUre that ecmtainors sre etupty by RCIZA eeite:ria prior to disposal in a p~rmittcd industrial taadftift, 1.4. TRANSPORT INFORMA170N air AU G, ? 0. i 9 9 9= ~? : u 6 Pik--.---~I'~- T D R I I, L I N~ ALASKA . ~ .. U.$ DOT' U.S. DOT CLASS: Not rzgulatecl. CANAf)fAM T'RAN$faORt: TDCaR CLASS: Not rogtrielecl, SEA 7RANSPOR7': IMDG CLASS: Nokrcgulout:d AIR TRAN$IsOFtT: ICAO ClrASS: Notregulatal 75. REGULATQRY INPQRMAT'iON N~, o3C4 P. 6 REGULATORY STATUS OF INGRi:DIEN'fS: NAME: CA9 No: TSCA: CERCLA; SARA 302: SARA 313: DSLICAN}: ~lm~Y u>~enrs Yes No No No Yes US FEDERAL REGULATfONS: WASTE CLASSIFICATfON: Nat aha'rardous waste by U.S. RCItA, eriteria. See Section 13. REGULATORY STATUS: This Protlucl or its c:ompbctenls,ifa miycduto, i~ subject to foUgwing rcgulatlor>H (Nbt nkant io be all ittcJu~avc - sClactexl rz8ulations repactrcniccl): SECTION 313 Tt-is prgduot doex mat wnrain ioyric ch~oical sutyject to 16e rekrarting rcquirer»ents of Scotian 313 of Title .III of tltc Supcrfwd Am~x~ent attd ReeutlywiaRtiou Act Of 1986 ancl4U CFR Pori 372, SARA 3I T Categories: 1; Imntodiate (Aouic) Hnaltlt I.dTrcis. 'l'tte compoucnats ufthia product arc listaci qit Ur arc cxciupt from the following intcma6onal cheyXtical registries: '1'SCA (U.S.) EINf?C5 (Eural-e) DSI, (Canada) STATE REGULATIONS; STATE REGULATORY STATUS: This rct or its agmponents, If a nuyctuce_ iS 8uihjcat ro fallowing rcgulatiane (Not rueant la lye all inclusive - adatcd regulatiom~ entcd):. None. PRaF'OSITTQN G5. This ptodttot cues aol contain cln~icais considered by the 31s~tc of Csiifbrnia'9 Safe Dtinldug Waicr and 7mtito E~tforceayent Act of l~-8Cy ae cat>9ing eestccr or repatsdrw'tive tenacity, and fire wiricii warnings arc now teclttircd. CANADIAN REfsULAlI0N5: REGULATORY STATUS; Thin h4alerial Safely Data Sheet has been pneparcd in cotttiFiilancc with the Coniroled F'ioduct Regulations. Canadian WI-IIvIIS ClassiticatiotLNot a Contralleci 1'roduat. 16. +DTHER INFORMATION NPCA KM13 HAZARD fNDtrX: i Slight Ha~,ivd FLAMMABILfTY: 1 Slight i•Taianl 5/6 "n'~~.. 20.:'~~'~ ~ a' CI?Pfi47.~~i-I ~kI1I1INu ,4I,ASy~A ..~ _,_ _____N0. u3Q~ _P., ~ ----_.._ . ... .. , REAC'fIV1T'Y: a Mittitnal Fia~rti + ~ NpCA MMIS P~ItS. PRO1E .INDEX; J • Splaelt Goggles, Gloves, Synthetic Apt'txt, Dust and Vaprrt llespirsioa. USED NO'~~5; N!A ~No[ applicable N/D =Not detit>ixl INFi7RMATlON 50UFICES: U6LlA Pt:nnissiMe ~~ Limits„ 29 CFR 1910, Subpart T, Section 1910.! t100, Air Conitmtittnitts, ACC~lH Thresizo[d [.unit Vahtea and Biubgical E:cpasure lndiona Cor Chclr-icai Stjbst anr] ltiltyt~cal Agonts (latest ecbi6on), Sax's Daugerouc l'ropcrties of lttd~ttixl Mat~elials, 9th eel., Lewis, R.J. Sr.„ (ecL), YNR, Never York, Ncw Yatlc, (1997). Product information proviclet! by+ the t:ommercial vendor(s). PRI=PAREp BY: Sant ~~askin REVISIdN No.iRttpl. MSDS oT: t /February 1993 MSDS STA7lJ5: pp~t,~ QATE: Febntary 17, 1998 CNSGCAIMER; 1NSD6t fualisltedaidcpcgdent oCprodtl~t, rile. Whitcrwery etPwt hex been trade to aac'walety desaibw this pr4duQ, su~ne of the data art: offtainod Crrnu aotu~s [xeyand o1tr dvayt Au~rrv;gian, W c callnat make sty aasertiaa as in Its reli86il ly ox completenesx; iii aret'pre, tusar mey rely on is Dilly at ~ee'a risk. We leave made nu e~'fod to oeelaar ur oonaeal dalaeriwee aspects oClhis produCi. $in~~e 9ve cautpt aritinipaic a aangtil thrl ccxgditiien8 ugdEtwitich lhia intotmrtiur~ and prodtect may be used, ive make no ~ttvurlcc ill ar thoprecsuipq wohuve aug~xateid wiD 6e adegnap,, t'or a[i etdlvtduaig attrY4railuat[ats- [L 1s the ubli~inn of each wrr oflhia product le c«nply with the n~qull+dtaonfa of ail applicable IaWR rbgsrdmg use apd diappaal u!'lhie pmmur~, Additicma! n CnrntaGat will Ire Cumixhecl upon request. fA aae~sL Qse une, however, no warranty, ei~leer e~rcvsed a ubpiied, nor tiwbilily of any aafura wiUi rcxpac[ Nthitc prarlud a to ilte daG~I herein is made or incaared hcrc~tder. 616 X10 M M TONY KNOWLES, GOVERNOR ALASSA OIL A1~TD GAS COlY5EIiQA'TIO11T COMI~IISSIOI~T January 1, 1999 Robert Menzie, Jr. Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Re: Class II Freeze Protection Dear Mr. Menzies 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 ota ~, You recently asked the Commission for clarification on the appropriate level of freeze protection allowed in Class II wells. After consulting with Commission staff and industry representatives I have found that the level of freeze protection required varies from well to well. An operator must take into consideration such factors as gas or water cut and fluid levels when assessing the level of protection necessary to prevent damage from fluid freezing within well systems. The Commission has no set policy or guidance on this issue. It is up to the operator to determine the individual well needs and act accordingly to ensure that mechanical integrity remains intact. Please contact me at 279-1433, extension 236 if you have any additional questions Sincerely, Wendy Mahan Natural Resource Manager Cc: Jonathan Williams, EPA. Region 10 ~9 ~M ~~ TONYKNOWLES, GOVERNOR ALASKA OIL A1~TD GA5 COI~TSERVATIOI~T COMnIISSIOI~T December 11, 1998 Chick Undenvood Marathon Oil Company P.O. Box 196168 Anchorage. Alaska 99519-6168 Re: Clarification of Exempt Waste for Class II Wcll Disposal Dear Mr. Underwood: 3001PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 ~~a ~ The Commission has reviewed your letter, dated December 8, 1998, requesting approval to inject natural gas condensate (NGC) and contaminated groundwater recovered from Kenai Gas Field, Pad 14-6 into a Class II disposal well. Marathon plans to pilot test a high vacuum extraction system on December 14. 1998. The Commission agrees that the NGC and contaminated groundwater arc exempt for regulation under the Resource Consen~ation and Recovery Act, Subtitle C. However, the Commission must determine that the fluids have been "brought to the surface in connection with ... conventional oil or natural gas production and may be commingled with waste waters from gas plants which are an integral part of production operations..." in order to allow Class I I disposal of these wastes. You stated in your letter that the source of the NGC was from historic production practices prior to Marathon's takeover of the field on December 1, 1994. Marathon has advised the Commission the contamination was discovered in 1995 as a visible sheen on top of the pad. The contamination. is confined to on or below the pad area and the concentration is restricted to the southwestportion of the pad, near production buildings. Marathon has sampled the waste and no other contaminants are evident. The waste is also non-hazardous in nature. Although it is impossible to determine the exact source of the contamination ~t-e have no reason to dispute that the contamination came from production handling equipment after the fluids were brought to the surface. The Commission finds that the NGC and associated contaminated groundwater recovered from the rcmediation of this site arc Class II wastes and therefore eligible for injection into a Class II disposal well. cc: Jonathan Williams, EPA Region 10 #8 M Marathon MARATHON Oil Company December 8, 1998 Ms. Wendy Mahan Natural Resource Officer Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Marathon Oil Company Clarification of Exempt Waste for Class II Well Disposal Dear Ms. Mahan, p~o~ Marathon Oil Company is requesting a clarification regarding status of liquids for disposal from a remediation system designed to recover natural gas condensate (NGC) along with dissolved-phase hydrocarbon groundwater at the Kenai Gas Field, Pad 14-6. The source of the NGC is from historic production practices prior to the assumption of operation of this field by Marathon on December 1, 1994. Produced water and NGC are exempt from the Resource Conservation and Recovery Act (RCRA) Subtitle C Regulation and Marathon maintains that this status remains intact when contained in groundwater. Therefore, the free-phase and the dissolved-phase NGC in groundwater is an exempt waste that may be collected and transferred into the existing wastewater disposal system and disposed via a permitted Class II injection well at the Kenai Gas Field. Marathon intends to initiate pilot testing of a High Vacuum Extraction System (HVES) utilizing a series of recovery wells installed on Pad 14-6. Results from the test will be evaluated to assess whether the configuration is adequate or whether a larger system is necessary for full site remediation. Marathon requests concurrence from the Alaska Oil & Gas Conservation Commission (AOGCC) that the recovered groundwater maybe injected into a Class II well. An expedited determination from you is requested so that the test may commence on December 14, 1998. If you have any further questions please contact me at 564-6435 or Robert J. Menzie, Jr. at 564-6372. Sincerely, ~. f Charles A. Underwood, Jr. HES Professional I C: W. C. Barron R. J. Menzie, Jr. D. R. Erwin - KGF File 340.90 ,~ r' 1 ~ z ~k ~ ~K ~; ~ R a~ t~s', .:':Ci AI~ Domestic . duction P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 A subsidiary of USX Corporation Environmentally aware for the long run. TONY KNOWLES, GOVERNOR ALASSA OIL A1~TD GAS COIeTSERVATIOI~I COMI~II551O1~T December 10, 1996 T.J. Kovacevich '' Operations Superintendent Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-616$ Re: Determination of '`Local Production'' Dear Mr. Kovacevich: 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 ~ ~o ~ In your letter of September 9, 1996 you expressed an interest in the establishment of "a definitive Commission position on what constitutes `local production"' for purposes of the exemption under the federal Resource Conservation and Recovery Act ("RCRA") for oil and gas exploration and production wastes. Natural gas produced on the west side of Cook Inlet is treated at various production facilities and then gathered into the Cook Inlet Gas Gathering System (CIGGS) line. The natural gas is then transported under Cook Inlet to the Unocal Chemical and Marathon LNG plants located in Nikiski. Natural gas produced in the Kenai and Cannery Loop fields is transported to the Nikiski plants via the Kenai Pipeline (KNPL). In the 1993 Clarification of the Scope of the Oil and Gas Exemption, the United States Environmental Protection A~encv (EPA) stated that "for natural gas, primary field operations include those production related activities at or near the wellhead and at the gas plant but prior to transport of the natural pas from the gas plant to market. Uniquely associated wastes derived from the production stream along the gas plant feeder pipelines are considered exempt, even if a change in custody of the natural pas has occurred between the wellhead and the gas plant. The end point of the scope of the exemption for natural gas is in the gas plant once manufacturing begins or, if no manufacturing occurs. at the point at which the natural has leaves the .gas plant for transportation to market. For natural gas, transportation is defined as beginning after dehydration and purification at a gas plant, but prior to transport to market.'' In a November 5, 1993 letter to the West Virginia Office of Waste Management, Division of Environmental Protection. the Environmental Protection Agency (EPA) defined '`local production" as "gas produced from a single nearby gas field or several nearby gas fields. as determined by the state oil and gas regulatory agency." The facilities handling "local production' qualify for the exemption as the equivalent of gas plants. T.J Kovacevich December 10, 1996 page 2 The Commission has no general authority to interpret or apply R CRA. However, after consultation with EPA Region 10, it is our understanding that local production determinations only need to be made in cases where there are no gas plants. A gas plant can be defined as a facility that liquifies product for shipment to market. According to EPA, since the CIGGS and KNPL lines are not transporting the natural gas directly to market, the exempt wastes in these lines should remain exempt until manufacturing begins at the Nikiski plants. Sincerely, Chairman v~~~-~~ Tuckerman Babcock Commissioner cc: Grover Partee, EPA Region 10 Kim Ogle, EPA Region 10 ~' 7 N _: Rlasic ~ CC~~~,1 ~' .. Domestic Production I CGt!i'~9 M Marathon MARATHON Oil Company September 9, 1996 ;:.j.^ I 71'CC L" s P.O. Box 196168 ~ ~~TM:?cn!. Anchorage, AK 99519-6168 I ._ --" R `t, . Telephone 907/561-5311 ;.; ~ ~ E-~,~ i Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Waste Management Dear Sir: RECEIVED S EP ~ 1 1996 Alaska Oil & Gas Cons. Commission Anchorage E__.. Recently, Marathon Oil Company ("Marathon") initiated a review of waste management practices at our facilities in Alaska. During our review, we identified an issue which we feel is in need of Commission Garification; and, in light of some of the ongoing changes that are taking place with regard to the regulation of oil field waste management practices in the state, we would like to schedule a meeting with you to discuss how best to proceed before the Commission. Specifically, we would like to work with you to establish a definitive Commission position on what constitutes "local production." On March 22, 1993, the United States Environmental Protection Agency ("USEPA") published a clarification of the scope of the Resource Conservation and Recovery Act ("RCRA") Subtitle C Hazardous Waste Exemption for Oil and Gas Exploration and Production Wastes. In its March 22, 1993, clarification, USEPA states that the exploration and production exemption ("E8~P exemption") covers ail wastes generated at the wellhead up through the gas plant. Ordinarily, wastes generated downstream from the gas plant are not covered by the E&P exemption. The scenario by USEPA in its March 22, 1993, clarification for establishing the scope of the exemption (i.e., use of the gas plant as the outer limit for what constitutes E8~P activities), however, did not precisely correspond to the typical natural gas production process used in many states. In other words, use of the gas plant as defining the outer limit of E&P activities was not appropriate because many gas feeder pipelines involve only compressor stations and/or other pipeline facilities and do not move through a gas plant. Therefore, in subsequent correspondence with regulatory agencies in other states, USEPA offered further clarification of its position with regard to the E&P exemption as it pertains to the production of natural gas. In this series of correspondence, USEPA stated that in issuing its earlier clarification, it did not intend to imply that wastes from all compressor stations or pipeline facilities are outside the E&P exemption; rather, its intent was to regulate those wastes from compressor stations and pipeline facilities that are part of transportation. According to USEPA, those compressor stations and pipeline facilities handling only "local production" qualify for the EB~P exemption. A subsidiary of USX Corporation Environmentally aware for the long run. N ~ Chairman, Alaska Oil and Gas Conservation Commission Page 2 September 9, 1996 Beyond giving general guidance as to the definition of "local production" as "gas produced from a single nearby gas field or several nearby gas fields," USEPA has designated the state oil and gas regulatory agencies as the entities responsible for establishing a definition of "local production." Because EPA has delegated this decision to the AOGCC, we would like to meet with you to explain our gas production operations, and determine how we may best work with the Commission to establish a state position on "local productionN for purposes of the above discussion. Ve truly yo s, iacL ~d~- T. J. K acevi h Operations Superintendent ~~~ H:\WP~oPNS9B1TJK99 ~6 ., ,. .. ,~ ~. J ~.`~_~ ~ Lr-~ • __~ t. ~ t_~ i_1 ~ E_~ lI-1~, ._~l ~~~\ Lr?':: ~` ronn~rc~vowcES, ooVERxoR A~A58A OIL ~1~TD Grams co~s~cRQgr~o~ corunQssio~a Stephanie Olson Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 re: Accepatable Class. II Wastes Ms. Olson, 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: {907) 279-1433 FAX: (907) 27&7542 August.7, 1995 n~o~ In response to your letter dated July 20, 1995, the following waste streams are exempt and therefore authorized for Class II injection into the Sterling Formation interval from 4468 to 5152 feet measured depth of the Kenai Unit 11-17 well: Disposal fluids brought to the. surface as a result of drilling, production and workover operations, including produced water, drilling and completion fluids, drilling mud and cuttings. Pipe scale which may contain NORM that is currently located in storage drums. New pipe scale and sludges which may contain NORM from treatment vessels for produced water in which the NORM sludges settle out. Soil. and organic material which have been contaminated with pipe scale containing NORM. Pipe scale and pipe dope found where tubulars are stored on racks and which fe{1 out of the ends of the tubulars onto the ground. The pipe scale and pipe dope, mixed with some soil, wi11 be put into drums and disposed of in the injection we{{. If these tubulars are stored at service company locations, care must be taken to ensure that no service company wastes are introduced. Water will be added to the mixture to create a slurry. Water sources wil) include produced water, fresh water from {oval wells, and/or rain water found within containment dikes at production facilities. Soil and organic material which have .~, Ms. Olson .~ p. 2 • been contaminated by spills of produced fluids, production waste, or contam- inated rainwater from secondary containment sites used for temporary storage of these E & P wastes. Rinsate from rinsing drums used to store E & P waste and equipment wash water. Gas separation wastes, including glyco{ based dehydration compounds. Stormwater in contact with secondary containment areas for E & P exempt waste storage areas and production equipment, onshore reserve pits, and production pads. Please note that the following wastes are not permitted for disposal in a Class li injection well: Oil and gas service company wastes, such as drum rinsate, spent solvents, spilled chemicals and waste acids. No waste solvents are allowed from any source. Please refer to the Federal Register, 25454, Vol. 53, No. 129, for a more complete listing of nonexempt wastes. Care should also be taken to make sure that nonexempt and hazardous. wastes are not mixed with exempt wastes, since this would render the total volume nonexempt and possibly hazardous. The mechanical integrity of KU 11-17 must be maintained in accordance with Disposal Injection Order #9 at all times. Please call if you have any questions. Sincerely, ~J M~...- Wendy Mahan Natural Resource Officer ~~ SENT BY~Marathon Oil Company Marathon ~.~.~~ Oil Company Ancharage~ 907 276 7542;# 1/ 4 Alaska Region Domestic Production ~10~ RO. Box 190168 Anchorage, AK 99519-0168 Telephone 907/561-5311 FAX COVER OTTER Date: ~ .~ Time: PLEASE pELIVEIi THE FOLLOWING DOCUMENTS TO: Name V v~r~ ~~ /Y lGt ~1~ ~' company ~ ~ ~~ ~ ~,, A l l G 9lasi~ ~i# ~ has Corso Commissl4t` °~~~ Drag Department/L.ocadon Facsimile Number ~7 ~ / .~.^ ~'c~ ~ /~ Number of pages (including this cover page) FROM: Department/Iaxtension ~~ ~~~ ~ ~ ~~ Facsimile Number 5d4-6489 8- 2-95 1~17PM ; NOTE: /~/ ~~ S Q~ yt`t~d G'tz)C~ S ~-- ~~ ,1•>< -c Gr a r.~~ S~~L -f h r'~ G TIE.. ,C-~.rn-r. ~ isSu~°c>~ ~ uc~ nca ~ ~1~; Iftrx~r~,smi~ssiore is not complete please call (X17) S¢¢1-5311. ~~ (1/eas,~ y it/~ ~e a ca./~' rhea b'lair A subsidiary of USX Corporation ~ ` p '~ l' . ~r lZc1d. ~ ratSa~. 'sc ~s ~I'ahi~ l"o;n.f" Gc. •/1. rr- S -~d~ ~~~y~-, , SENT BY~Marathan 011 Company 08~02iz99S J.5: ~~.:..~ ~f,46_ Prd~~tat Rry YnaIR[+rat. tt:norv 1i7t4-~44t»1-l RegtrletorY tlatern+Ntsllott Ipr 011 (Cei ana ~eeltttetm+rl R><trlvr>ttlon, OruNOpMMnit emra lrtidtretion Wa Aarilltr+ReAtrlaWry deturtni»etk-n. arrtrrlwanr: Section b0071bN1R)ID) of It ttaoovrae Conratval{ptr snd Aoeavm Aet (itCAAJ h3quirer Iho Adtnlrtittrr to dateamine whrthar M pro-rutyttla raytdrtbru untkr RCIIA 8ubtltlt C f w+rrter !ram thr ortplorstipn, davelaprssnt, snd protirotian of crac ofi, rutm•ri `t-i, end pathantwl aonat 'The Admtrtrtmror nnrrl tuakb tlrlr detettalttatiart no tut•r than ris mwtt nltor oomplating a Reporl to Conpror those wrrta and roar prowWiry rn epptrttttnlty for pttblla aanttrwnt. 7'!~e Agonoy hee ron-pltled Iher.. rclivilit rnd ltrr decided that raRr+lrtion ands IiC~- 8ubltde C tt asst wttr~lanttrd. Rbther. ~A wilt ietpCenrnt « threo- pronged etrettgly io rddrpro the dlt~tt envirarrtntnwi and ps0ttrogttnatia irr tw=ad by tttOrtt waster by )7j Jmprov l`ederrl ptoRrarnt undarartlNgrtR nuthotitlta is SttbUlle [) of RCRJ1, tht Warn Water At:t. And tibia lkirtkittg WrterAet; th) wtu4irtp wtlh Staves tc enaopteRa ahea~s tp thalr ra=uirtion rnd bnlor'cvtnont to improve Coate prnQnm~ errd.tlt) working with Gandrarr to dwrolop my addittonrl rtri~~` ary attsiwritirn shot .try bt oak rodwtr+rttat tarot+tnltrtAt+ CnWTAttYt Fos lartMr htlarmatlan air the t'tlJulst dattrrrtttnatlon, bantact tlta RCJNI Sutterlttnd hbttire al {ttbt)) ilat.BJ+ErI It ir'eeJ ttf 1~13!<1r.80t1D. S11rt~MCAr11' rrtnattASTto-A Pr,raarMa tJ~+tbw. 1. Srtgttwry n.t)ackerovnd A_ ~'ei:hnkel Srrratrty at Nnyur+ la R.l~icpot Aurf+arlq~ ~ Ceaducian. of tiN RrnwN ro Crnln D. iartara+~we die 8rear of IAe• cat. t ~ Rd~aAd ~~a~tittty Aetere-laattsn Iv. p~~ Dnrannin9tioa la Gtado rnd ivaearot Cis. wa.l.+~ A- Hrittd Arrertrnebt A~ tiue+wraie Imtuct Awni~ri. C Adegveey of Stara ewd ttadmxf rG+rvtrtty~ MoCrae+s D. ~onelrilanr Y. Ltroru to rinpwae Itwto awl! ivdoral tsrrntrom~ X, aeaertd Pro~+r.+ te•p~pvcolantr ~~! F-+~i6liat ArlltoritiN n..nddn+ew•! Radrwr Arrho~rv. 8- 2-95 ; 1~17PM ; ~ ~~.. DEPT . ~, hie. 7.'.C! j t'Vnt1 G 1n+p+s4wMgM~ IA til~Ity iM~-pnwh. Vt. aetrriaery tiatrm+rnxNen kw teelanrmal ~'NRY wet-M A. Ilorwht ArMrri+n+ner G4 AtlagqernyetaE~wuatW Ir~t,Mxwr IWsdulattena C 11w-dMalaer Ytl. Rrre+rttd+. ~+:nt, ++nd D+r++emlrrrtar ~ Vltl. atA ItCM Wckot _. Sutrmwry lr 'Pitir t-cNOn proarnts Utr Alongvy r'totdsltlry doterminrlipn rctittiratS by rt:ctton SOtItIb)),.~16) of dto Reiorrce Goasavollon rn0 Rranvsq Acs iRCRA) for dril;t»p Mddt, tnvdaaed ws+eti. snd othnr wrsr+n rreoaistrd with lhtt ~' expirratlah. dvvalupmon4 ~ PMdxetion r 'ot r:nrdo all, rloteuv+l dt+a, ae t{eotheerttsl on snt~~err~~' RCRA rogalrsi thtr Adntlnidtrstnr in determine olthnr to ptonwlgrte regtrttrtibtti ender tiutttlttr C rot tAlrttea from otl. •p+i~ t>rtd ptf-thennal ttttplowlfen. de~•aiaprneaL rnd p-bduatlon. or the w4h thgslMttonA ate urrwernnted. In mektng tAlr rimr-atlrtrgott. thr Adminlrtrator it e rtpolnd to ot(lla Inlvrtratiun " ~dewrloped snd soermalated by the re Agency punlaenl to s rludy ro~~tsad ender R(~, rotulan t100ztmbl`an A~~aencyy completed dtir study rod paWtrhed tit rcrn)tt in Dbtrrrmber. ~~ +n o Ropofl (0 Can~ryi tittUttutt "hlanrgomeur of tivarror frets tbu Iatphtrutit+n, Davo)oDrnant. and • produoUS» of Crude aft, Nstueei Grs.' trod Gtrothtrrmal l,.ttarpy; •ln oot~slteq tint Ileperl to Con7ran and tltir tutntirtrtton. ENA aelht-t+e4 and rvslvatad taforrnrtion on all of the erwer wired Irt ieettaq ao0",dmJ, insiadhtgg three ~ faotort paelsinin W } warier from the ertpMnttlon . 6 dwdot>rtrrat, and produntt»n of oi6 ear. rnd><aathraxttat aner~: (t)'ItAe chrfrbteNrMee. ntAdt+pmont prretieer. slid reru)ttn itnprcu a! theta tt+ttner tnt hettutn hoalt~ rnd tMt rnvtrtpt+tttmt» {~) tht adapusoy of sxlit3ttg 9toli a»d Abdetaf reQtttators prori+vnrar and (~) tht: eartrtomic Impeeu of a»y adeUttanal •• -egtdrtoryeonrteEroai»tlwtry. •. . i» otrntsNirrtnq the !fret let:tvt: F.Iit• fussed that r wide variety of »rrnapomont prat:ttoot err utdtiad fe-r tt-eee wtN1tH. rnd tltrt morn' rllert+btiwr to theta ortrntt prrcticer are not teea[bie rr appliwbic st Intllvldaal alter. i11tA ltttu-d ihrt oil. grit, rind ottothrrnwt wwofeta attpinste M vtny direrss reoltialc sett!»gr rnd contrin a 'M{de vrrlety ei hKaedaur annrrttuonh. 4A rM!~t~mantrd tta drnte~ ours raslthtg fran the mrnrRar-anl of tMrr wurtra, t toand thrt many of thou twrr In vit-hrtion eF akleung state rnd Fndorid raryuttamrms. ~~~ ~~~ Anchorage 907 276 7542;# 2! 4 7 2581 P.O~ Ii. ]U utir,~tri Ar to q-tt raavl~ f.u+or. P~'A tot+nd chat axtrtlttR titttto and erdttrat rtrauluttanr aro Sanar++liy atlequwb: tv r~mtrni Ure maerttietnant at ail •od Irllr waetar. Crrtrtn t+l~ulrtory )tale do ttrtlcl. however, add ewto-aernoot of oxbllnp raylutetipni in ramp 9to~as ii Inud+lfll+et~. Yur a>Kadtptr. e0mb Slt+ler hbvo lntuficiarn nantrtrlr nn the arc of ltrndfstrt+ina, rtltt-rprugtlirq), nit eonrtwattap end wrGtt:c wntnr dirchrrpu pr'aotloar~ tiwrrx• $tr IM Iur.L rwftiWttnt wrttrolt fur ccntrnl dirpoerl and tmutrttertl faaliitlor rn4 for Ntroctgted Warler.r Theexlstinl 1ruJorai eta»duMr under 6ubgtle A of RCitA provide gonorr! onvironntonful perlormgnae rtandrsdu for dhpnrrl o! ral)d werlsr, lnsludiwgplt,grta, and aoothsretoJ waetae, but thtsrr ruutdardr do nut luhiy rddrers the t eil)e aonobmr pttsud by oll s>sd r: warns, NuvaMhbkrr. k'PA her rut~ority Yndur 6trbittle t) to pmmulgou- more whored aUrtrlx. [n WdlUtm, the outharllfei yvaileble under the Ctraln Water wct ICWA) sr Sek Dr{nk1Ag Water Aot ISDWnJ een be store broadly ulgltred. • and rffarN an blrstrtiy ugdotw~ly to Ni grpr tindsr tMrc prtrgnrma ErPA'r rttriow 41 the third laWor luy»d that tmporhton d trabtl ik C rayalationa fur all oll rnd gvs M•astpA va.1J wbiret btllioni of brrre)r of wee to raguta riun candor SuAtitlb C re hrsrrdow tvaetar rnd wwrlJ csur;e b re:vcre eeonomla Cmpaos qn the industry and t-n oii rnd Qas >arodtrrotlsn la for U.B. Arltlittanally. braaure a krr~~t parr of their warlrt is meraQoti In ofl•rita ootna+erotel tttCClltiyy, rernovrl of the exemption oauld cuaia ravrrr shott•torm strslni oft lbe eupaci ty of SubtHle C 7'rerlrnent. SfOtsgw and lifipoerl Frciitrtes 17'BnFsJ. and o atar+illt:ont htanare to the SsbtttN C pertrthtlag burden !er Stata snd ~rtdo>rai httsart}otsr waste prgpramt. As tttplrtned to rnprr daft!! to bnetio» IV at thlr r-vtice. BPA fvvad il-pt regulaNan under Subdgp C nroaenis eawral ab+rlour praWenu. Fins. &-hutle C tarstaina an anuntwtly lards nltntber of .bi~88hty~-tNllad rsomtory »qutrgrnertr. It offers lhde tlytCwlity to rrka tnta eoaount else vtrryirt8 proteSkri, ciimuiolugltwi. pnapraoh-c. er+al other dltYettntcea charaotedaht: of ail and a~nti d+tllils;t rnd prodrOtfan•seues su+ur iho ooantry. At tiro pma ttpta. ii Haar trot ' prevido the Adt»ey wttb stn Ats~ctbillty to canridat cotta when applying Ihoea taquttomeMe to oii rnd pea wntae. ' AHae~l wo~tm~ r,a +hae' +~wnM« efhcr +t.ea p*adwsd tirutMr. drlafar mac. ne arniwr a~a 11tWYYtl lhu+NR f4lrillYltl IA akrNlrllron. {rNt+rtNr~atlN ~Ad rrrudw~aa+ O fdllaa all gad nehxel Nee. rye Ywman» +t Vrd,rw AIIG a2 }99.~ ~aS~sa Uii ,3t Gas Cans. C~inmisst~.~ Anchar~ge SF~VT BY~Marathon Oil Company 8- 2-95 ; 1~18PM ` ^ , 88i02~19`35 15.5P MpC LEGAL DEPT, t:sdat'et_ R•~,,a~tyl. '~, Na J>w0 in Ah-aks. itte Cal! t.orat ants Ute ntrpalachtan Statsr AUttt, dircherat prrdreed waist loom strippes wdi ti aurfrt:e watrra wore eeNtrsled to p t:nneer -iriy araaler /hon ot+r fn one handrod tbouiwnd !n roughly 77 n of 1tM eoeatarVaNve oases sludted M quartiNtlva H,k ntodelit~ far90tlt patnGttlle pt+odrttrd water txtiatltua eoncsnlesliotts. 9. Far the ttatla- oti a wbpJa, rrawlatrep oJt+r/ 0l1 and Qas fiord wA undervnntodlliedSerbtitre CoJRC1t wsard hove o eubtanirol rrnpnot on U-S tvonoRty, 'boa spreef»~ witA 1 cottC}ttaFDn did sa att+oagly attttitlp t!I RCRA redtllotlons apptiad~lo the e:tt all tad twtrral pas industry world ihr leas of a,l3nifiwnt nttrnberof J Satre and thN AL"1tA regntagor inttssse oil ftttpotia and pore a notlonrt sat:aM-y, Othsr, tdritasd th ihr potottUal costa to indretry Mwe urtdlnaatimotad - ' Thoatr In tat`ar of rastdattng wyia dtnem~tget~~tantil!tyywd to bs RCtt/1•bsaardow eoonarnic a of UUoa, rbut ncvet#holtna ballet-sd~rt saah wsa sboald bt diapowd of Cansi,tspt wt ACRA l9~nlJtitta ~ ra~ait+etraata. . In apsdfla aotnt^aMa on the mathodolo~pl+etr yaed b snatyst thnrt isatKy. eoaasaammeaters brttrwed t lire lower o8 8fate modei tnr,ka or undersUttr COs+a and irnpwU to f rapiona. end Thal defy tit»[tatiom t a><elsslonr of son-c scares lad 70 undprrtstad roonomia itapseu f» all Feep«rieM Sosts aotnrnt:tttrta sisfsd the nwnirer at ecanatniarUy ntargtar wsllr that woald br lerosd to shut I! RC:1tA Stt6title Cra~ubtions wen ttnpewd iu. bren aodttrortirr,ttsd, a Ihrt otatair rssumpgMr to rtes err tatrrrttau~ $~ OOrttnenled l i the arstyai, ignores Imtrogs set undisoovrp~ seart~ reservrr and Drodootlon. Tektnp the oppoatM point of view, other Qottttarntars atgred mat the attalystr 1 tees public hseith tsostr aswdated wltA oongmtsd ~~ dlrposal o! trt+~ds oil and natrtrsi grr waslst-, land that the trpsrt dotes nol takt trio atx>nwt: the tinrnala! sanwgqwaca of wttlatatttoNart of ground wstar end athae flattest re.ourcos, b'wate alaWOtl that Mttp.t finatlpa! bttrd~rtr to Mttpslrps to mitigate anvtrvnttmtttsl tlrrrtaar, so pracide heaittr taare, sttd t9 twatain fln.ndpl button front loaf prodsett 7 gill be iroats* tha^ firm taaal to the ail mad t-sltint Sas industry to ptrvs I t5*t d^rnsae, Thr Aganry bdlersa that lu srutn i ai impacts l0 Urs lndwlt7 of full rct;ui: ti an under Rt~t/15u6dtle C a e rooroaable snd tt-at ruck Impacts vtadd oJ' De sttbslrl-liat, "t'br Agtmry sakttowleddoa th^e coats trtutrd w ae AuWlo hratth eifou, and sottloaunrtlan of pnntnd wateratld rthwnalural n1 roroare^• bacaw^ trt tmpmprr rtisyas^! M of crude oil and aatural gam wastes hrvc trot beam dolrtttttited. 70. Rttpalatlan oJnlrsnrrnJrr wpytoa anderJull, wrnrudrfesd At;AA Si~buYM t' oppsals anr+sara,ery cad idprvctlea l of N thi. trine. Optaion vrar elwldsd oa this Coa-elttstan. Those agwsltt3 did ss t+ st vrhtla thou oppaad pensrolly a rt^te l1tai (t s wratr t, RCRA ~ hat~ardoua, it should btt t-satsd finder RCRA rgtalativna rsgardla:s at Iir less atlgin, Many of Iho.e to diaagresntrnl with thin aoncinatan srpusd that the erttds ol1 and nstgral =ar tnd nrttrt~~ tom to sftord ihr lbtantyal btndo» of RC1U- aUnn. ap er msama dmtertbed Io SaWlan tV of ihb rrrpulstery determinstlt»r. the ANttay oottUnus. to brlisvs that rsptdstialt of sll ttt'udr dl snd r-atsrrl par Mrgstas itnderttt:R,A 8ubtltk C la ~ t+ruartas attd impyplleal. The Agenay balsa Ihst t!-ns waits non be maaugsd to a tnsnaor rq ar to protoW Atn»sa heolth snd tbs onrltaatnsat wlthost tsgolslhtg thtaa r»da Rt ~Rrt 9ubtttls ~. !Z, 3tass htrve odopted vorlaAlb opAloaaAM t0 wnrtamonogtrpent. Moat aemmsrtlsrs aprOSd whA d><s condusiot+, but thgs wr, ao»sldenbfr ttisag~pnsnt over whether currant Stria it reputattorfa an rdsquately doatsttod surd • enfotaad, n Vatirbls oppe+aeaher to wralr ntettagamrnt s>•a partly the rasnll of trts+Lnp ttwvleortmenai aattdittoar- spr~~ldu~detr litatae. rpr- Mliwee.~ borwwts thtt lbsne sre.teny aaaoa whor, atotsi attinpsnt uttetsattla are both bsslbls rnd dsattn~, and that ataxy Brlsbl have reoo~-ised tJds la d+a»p, tnsda to th.lr ragulsttona in the NN few ysura. Rama t3wtoa have t^ke» dp^lAatttt Madatai-h- roles in toes dawtoptasM of mate rnvirortmeatully FrstssHw rrquirsrrettts, 13.1 a-tation oJsxislrgpSlata and t"st raqufrrtrsttte .t, a t;totro! lamest rn JortrwktJn~ »roontnte»dotl4ua to rseparrt to t»otrdrr dpDY(m~ O;riritm was dividrd on !hies a-ncirrloa. borne ootntrtRrttars wpod that rxlatltgl State and f'sdorai roiulallora ste adsgasta mad tort addtttonal ttitata or Frdoral i te$nlrtta>a aq annswssarg at+d imprao/ie^I. Othrrs arptrod that axiali>w~ 3tats tad Ardma! reN4rtfotta have not t been ad aataly aoldrrrd tad thrt addltlonei Fadarsi nagulxtlgru arm neGeasury. Anchorage-~ 907 276 7542;# 3/ 4 71,,,6 2581 P. @3 d, Thfa Aponcy bupotiar that thi: floes ti enforcrtnrnk anti katpletorntatlon a~ aon rd~iarly be rip vrved. ~'luiione Pubtk eXinr»nnta tM lirq Gratricvsrol Enrrpy/~er~twNt of ~K ra t:a~eyrotrr• only two taMtms>sts rpet:tAcaOy odcfMaaad ~Vloihtmari aneTp~l MMatab One tbentaantae ptwr»ted ~ddlllonnl lnronnalion rClalitl6 to datn,tgaa rawtting from the oClsfta diapoat of AovtMtsttttal eatt$y production w~sinr lauch as bydropaa wltida abrtettnttt wratea whtoh tart ttonhrrardous by twliforaitr atandttrda~ n oot.meroial I.t:filtip. Tha Informrtiat alisaed potontisl dsmttgsa~r»dlol~ dsk Dy c~taeslnattgn o! stufroe mad tlrotwtd twtoe lroin tM dlrptlssl o! hydro~on aultldr abatautgnt wgtrM in asntnWtod ar emattneettsl dirppee~,a) firitpttra In Galiivtati•. These ft-~ittee mesa dnaotlld ^ttxaly for the dlrpsaal v/ dstst»tiroi+o0 tR b~ttonb°`tdgwe°in t b tpr Callia~rnls standardr. 7hs other oasatastttrsr spsottisaliy eddnaringgaotlttta»tal+ptw~ fully rup ottsd tM oottolurionr al fire repprt at~statad tbst fits Calitorair atatttta, t'sgrrding tbs tarMpottro»t o~ gr-ofhettasl sn.rgr wssir~r arm t+!}Itaslw rrd rilfscUve, 7't+t: Adtmcy gonuntts, to beiia,rtt thsl grotham+d a»~ergy waatae err gerarally wef~tregttlatsdmtdsraxhtflttp&ISisand Pbdrrsi ptparrnn, Howswr, the Asanty raknowtsdgs, that rt least oae ri8nlffotutt ttluinitwbls dhpvaal proattatr u octerrlnt and hrr taketi- thir Into amsidrntion In tnltlCietp thta tlattt rapdalm~ datrr:ltinatbn, A l>sKStml,tol/oat o lAe Saopt wf d-o 7'eRrpatar~- RCRat ~1tlptrOA 9aasd ar the I.~gtta~~pI. er >Ittaur reetlvp ~s(bNa11N) of the lttro .msndmaau to tit'~tA.rsvirwof tlrtt ,restores and ruppowlty lsglalatiss ol~ing~w~rta~ wen 6tctttded h~tho trtnpotrry tocempllon tut Conti to the rtrltllR. • rooduosd waton • D>•Jlkag llulde • Dtirl ostttt~ • fttpwaah; • Drtl:tag ttuida and cuttings lro~t- ot(rhorr operatient ditgrowd alartairara; • Gaothattnt-t p'rodttglioM- fluidar r~ rttth~wt~ h~~py ab.tem~i ~wr.ste, !r ->a9 peedustitrtt. • Wetl co.tplslion, tesatmont, and stlrn^isttgrt natd~ • ttr,sic aedlrneat attd w^t^s tad atLe: rank bottaarr from atoroga Csdlhtrs :hat held prodwrt attd srtgtpt wartaz C~~ ~ ~y our o~ ~~~~ Gas Cons. Lotr~t~~s~~~' . '~ .~ ....~.._ , pnchors~s SENT BY~Marathon Oli Company es~av~~9s ~5;. Teeiat':l A~umul:etad eraladrls each ets ' hytJmGlttbvni, tolidr, sand, and antuialt-rt trtrm produclient erpanttora. ~: said troutinp t+ortalr, and ptrodrel lots impousdsranttt: • Ittt rlwteot andcontsminatcd Gattvtni from s tortpa or ele(tnM•t of oxarnpl wrslol; Workowr w~rtor, `'~ • Gte piOnt dalndrsttoa w-snot. linalttdin~ glyaoMl,eiseeiovmpotmd>t. t1Nae! Ittlslra~ Ahee tnrdta, bac~kaesh. and moleouler elevY.; • Coe plrnt ewtteteusittt wssfnr fw sulfur rsmo~t-rl. Inolydtng eminta. trnin nttt:r;..ntiss filler ttrrdir. brckwash. preeipiutsd ranlete rladgs.~ireM rpo i<rnt bydrpfson aulfldo ux'ttb{-or llquld and alwt8e: • Cbn~ng IQ'Yrp~ liJplydRWtC • 15pent [iftrrr, tiltrrr+odlr.and ireC}tvrYi}I (olrlunofetA the: lilteritrdl'•is not hattandour rrtd 1M roaidga in N lr hunt trn eteompt waste rtrsrml: • !'uckitt6 liutdrt • protiaotd ra-d; • ~~. Wps oak. hrdtao.rbon salters, . hydreltre~ and other deposits rst»ovod from piping end sgsipmsnt prlor'to irtatppeerrttatton: - • Hyitvoart~ort•btrrtrt6 toil: • ftigginp wants trornyy~~eeihering ittee . • wanes (rtlm substtt'feta pro Berri end rotriwal, e»tewpl four the nont~camp wastes tislyd halaw; .. - •. CnnsKntenq retreovtd fwro- ' prod-tcad waurbrfonN fs lnteetoa or otleeewiet dirpeead et, .. - ` l,taaid kydroottrbons ttrtttovsd iron the ptodaatlat rtroam bvl not tango oil retlnihp; Gear from the pprroduction;trRtttt, ' such ae hytlsopan wglde rnd rFrboa etioetidw sod volatilierad h?drocerbona: • Mdsr3r 11 t-tt:ttrd front a pradttt:trq wcil doHh6 the prsogr iGttowA trs blowdown; • Waste ctuda oil fotn prlataryr bald operruonr end ptodtalton; end • f.lghtorgrnlasvol.tilt:cdfram ~ extanpf wNtitrr ip naeris pltr of Itnpottndatmfs eupt'oduettpa trtftttpfntr Thx Wit' br;fiava Wrl tha foflowit~ wrttt:t wen not Nrcladcd In the ot'~tai otttlrryrtioru • tfnueed tctetnrinO tltid~ or acids: • Car ptrat eooltnp lower elewainp M'rstas; • Palnlln wattage • Q;{ eht~pae rtrvice cnmprny wears, euvll •t tingly tltutttt, drum risu~ns, ratamm frock ransom, sundlda ttredfa, paixtit,g woslos. spent wlvcn sF:ftsd theeente:ats, trod Inaatr reWs: Vacuum trunk and drult risrsrle lrolri truckr and drums trMnspvrt:+',p or CCntaininp notrrtampt ~6alt:• • RstlnsR' waura: 8- 2-95 ; 1~19PM ; i..EGAI. DEPT. Anchorage 907 276 7542;# 4/ 4 713 2591 p. 04 ):tin' d, zeo6 ^ Lt y'altl tntl ro1111-arpfrM `rsnt!nucvt b} crydo 011 a:td trek tttYttorn roclsimrrM • lfrad stptlparottt iYbritatlimt,nUs: ^ Wei10 atlmrressvr o7. filtcrw +end tde~rintvir • thud in'~»alia nYidr; ' • WNwtR aaiwetnlsn • ~~'reu in V~ntt+Onation piprlinp• rctaMd pb~; ^ C+tlullr e» Ytdd tanors+rt7: ^ Boilttr clraniaq wsptept; • Boilerrrfrectvr<' bNeks; • liotlnr rtlrubhor A,eida alutipoa. st+d ssht • ltNeinnrrltlr arh; • i.nl-o-Ylory wgttar; • Ssytihsr~ wattlNl; • Pcrticith: wrttea; • Radtwtrttve leaeee waslrr: • pfytlttr. tnrul.liun.and snitte~lNpe-eua aOlkit Jn order u tietnrminv Ute scope o! tha cltcmpdon. liar Aptnor rn.isw+sd Ihr ttawta rot: kgttlettre hiatory• 7Tht , Apenny inttrproli tht to:tn "oths:r ..aunt ensexasted" to itsolodN rittwash, drill cuttings. tpd waaar arselad b~ agents wed 1n tsoiittettnP :ha axtrectir~n•~ developtnant end pmduotioee of the rlteourat, tad wwas prodovsd by ramot$t16 eanttnltnents prior to tha ttOheportation orso0aing of,ht resource: Drill Cutlln~r and N Na>e!+ rte gtttetntty co-minded wltlt tiNllina mYdw and Ihr A oy [oe~e hest proYaed thus wtlh ierpe•~rolutns warier for ' patpotti of dleaueelon is (11:1 .dstsratlnetion, ?he nmrMinp wssics on lh1 rbot-t ifet of ats'tept «rstp are t:anrldttred "aerooftted ornate," for grfrrppcc~tIart of lair det~tnttloti. Tht A oacl' Star detaurrnMOd th^t ' prodt~ rlattr tnfraed for e:,hat-attd roaorory Is not a waste for pta~roses of RGRA tetpylrtion and tharafara !snot iYb) eel t0 CtmtMll undsr RCRA titsbtilla C ar ItCiXA 8ubtltlt D, f-toduoed wear egad b enltttnad raoovetr it bare~'it^sslly rscydod ahd tr rn integral Pan a! some crude ell rnd atturt:t Cor prodttetlonptocerres.l'rods:cad w•rtrr irlectetd (n thft manner is alrsrdy ropalrtad by tht Uods:ptvtutd in Salton Gtttteoi program urdsrtht rats ~itlttp 'l1'IsiCr Ad.Thr Agrncy~ notor. however, Ihal If the produced Natcr it sivrcd in surfeca:arpamtdmsau pr4ar to in)erelivn, It tray be srbMct t4 l+t:P.A &u[:!hls D ngu:ellanr. 111.6seaers Cartwidsterd in Raprtrtorg pvtrttedardae tiectitln 30~7](t+)(~jilil of R13t:1 sIYICO tF.:t;1, rnrkistp tho tote-:otot}• datorretinstioe, 11tit Apltncl' mYN °Ytiiita eht htiortnetlon dove oped ar eoaumttlYfrd pturusnl to Ltis elu:l~• rrquu-+ad uttnar region arrtY(tnt; ' Clc~iiT, Cer,~roer sm'tstRtrea Iltot the dsltemirutlintt wetJd Lc hnrecl de nq loclors srytrclGcrllr emnrnotwtatl hl aoniun ti00:trn). no wrM ra A;t+sutrnl bsnae raiA~ h ' tl:c tRxt of rttGtlon ti+00i!(et) ra Y w~tola.'rhorebro. ie making today's dttorntinrebn, EttA eoemiderad not jnst the itnprCl Of thoea wratYr on Ituenan 1-aalth sand Iha enWlYUtmen6 but ntNO the othot Mornre Ihrt AG13A faction ttttaztml regaltrld CftA to retsd~. S oct!lcalh.l~A oonaldrrad thm rtsa~r favtprs in dvrr~elaping thin drtarmicatlott: (3)'f'!to tttarnsudsitc•. mrnapsenent preciiatt. and Itnpaett of oil, qae+And lhenttal MraeWr on harnan hoalt and the anviro»me»t; iZ) the rdapueeyy trf YttltUnp dtoto and 6adorat rt>Bulatory proprarne tut oantrolG;ng there wttrter; tad (a~ 11ta tr00nOtniG IlhpaClr of ettty t#ddlltorttt t'opulatioa~ oo it.. sxpttrratien for. and devalaptnant and produettionof.etrYdt oil, nawr•I Bus, and Qeolhtrrnt) senorg,•. Sat:dtm aoo~(m- sequtlwd 1'iNA to stud}' csth of there fatatorr. tt-. Ryuhttory Astaraetaatiaa for Grade Cp rnd Natterrl t±es ~tJntta 11te following di.ctrtsion rtnptnerlwr infttnhrUon on tltt three major fsmore (dteoaeetd~abot~e) used in toektep thlt. rseulatoty dYttttmina tMn and then presents t;pA'a oonCiNSloor and rationale far the sputa tort' dptsr~midrtion fot tmndc oil and ttagonol got wpsttrr, rho infen7nstlt.te - ru,nmari:ad ttertr incorpgref et infotmelloa t'tlgstved darlte6 lhs: pYtiliG Ct1lMnent period sod additional rrflntrtns»t of tht d*ta prtsrontod IA 1:PA'1 Dootla:hm• itm7 Rrp~t to (.onpe+rw, ~ .. ~, /l+rsordAsre.rmsnr for -ht Ropori to tblagrear, >iPA conduotad a titalterd stteigsit whloh n-ndnted the pot+rntisl rlfoct>r of dhptirxt of drilllttg rotate In rotttwt plte and tote dlrppuural o! prodvud wrtsr lip underprornd ittjecHetn and frtsrrl thrt tits petenitat risks to human Mellh hod iha q+rtrpnenefnt nitre rtnYll, Only n fnw aeroLttletsts appsrot'vd Io l,s of tralnr crntt;em when thtte arJStcr art: tnaltppcd in etxordoltM.wlth exlttinx Stale and Ftdortt rrp~tleitioltt. Tha rdual throasr perod wem iett'aslp dspettdtnt upart.ils-apsctf3c factors sueti at pgpuladoor sr rsnsitiwc reottrsir7M, Olhor tea:torranent practlaor ruoh as reprr{pr of prodtecoJ watae in'unlinsd pits were ew1 modoiod and msy pots itighor r1Ykr. nnatt~is of said date oopaawrd by GpA rnd prwesnted ttf the (anaerr 1667 lat:.'tnical report rhowr tart a partiuat ut oli and pat wr~tae lutntein aonctttoonts Mme ~ ~~' `fir At1G ~2 19~~ - ~i# ~ has Cons. i,utt+t~t~~^~'"' .,.,~..,. ~;ola~a #4 • ~ Alaska on Domes reduction M Marathon P.O. Box 196168 MARATHON Oil Company }3~ ~- ; ' ~ ~ ~€: Anchorage, AK 99519-6168 °- ~ " Telephone 907/561-5311 July 20, 1995 ,r ~( ~/ ~~~Q'- ~,~ s~ ~~~ '~~ -_.. , Ancrtor: Mr. David Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Request for Clarification of Acceptable Wastes Pursuant to Disposal Injection Order No. 9 for Kenai Unit 11-17 Well Dear Mr. Johnston: ~` Marathon Oil Company ("Marathon") would like to provide the Alaska Oil and Gas Conservation Commission ("AOGCC"} with information on its plans as the new operator of an injection well, and obtain concurrence that the wastes that are anticipated to be disposed in the injection well may be legally disposed there. The wastes will come, directly or indirectly, from Cook Inlet offshore oil and gas production platforms as well as from onshore production facilities owned or operated by Marathon and/or other companies. The waste will be wastes generated from operations prior to the LACT meter where transfer of legal custody of the product occurs and transportation begins. As you know, the AOGCC issued Disposal Injection Order No. 9 for Kenai Unit No. 11-17 well, Kenai Unit, to Union Oil of California (UNOCAL) on November 16, 1994 ("Permit"). Unocal and Marathon notified the AOGCC on November 8, 1994 that Marathon would be the Designated Operator of the Kenai Unit Area, which includes that well, as of December i, i994. The AOGCC transferred this permit to ivlarathon on December 5, 1994. Marathon and UNOCAL are currently negotiating their SERVICE AGREEMENT Felt WASTE DISPOSAL BY INJECTION WELLS AT KENAI GAS FIELD, and, as noted above, we both want to confirm with the AOGCC our understanding of what wastes may be properly injected into this Well. Section 13 of that Permit provides as follows: 13. Disposal fluids will consist exclusively of fluids brought to the surface as a result of drilling, production, and workover operations. Typical fluids will include produced water, drilling and completion fluids, equipment wash water, drilling mud and cuttings, and pipe scale. A subsidiary of USX Corporation Environmentally aware for the long run. M .'Letter to Alaska Oil a~Gas Conservation Commiss-~ July 10, 1995 "'° Page 2 of 4 ~`~~~ The Permit does not expressly state that Exploration and Production Exempt Waste ("E & P Exempt Waste") or NORM Wastes maybe disposed in a Class II injection well. However, based on permits and. approvals granted by the AOGCC and EPA documents, Marathon believes the AOGCC and EPA traditionally and correctly have included as waste acceptable for injection into a Class II wells wastes that are associated with the exploration, development, or production of crude oil or natural gas, that is, E & P Exempt Waste. An example of an E & P Exempt Waste is rig wash, which this Alaska injection permit expressly allows rig wash to be injected in this Class II well. List of Wastes for Injection in Class II Injection Wells We would like written clarification that the following anticipated wastes are approved for injection in our Class II injection well. 1.One is pipe scale. The pipe scale will likely come from the tubulars and pipes once used in oil or gas production, and possibly exploration operations. That is, the tubulars and pipes had been located at the production or exploration sites prior to the LACT meter transfer of legal custody of the product occurs and transportation begins. The pipe scale, some of which may contain naturally occurring radioactive materials ("NORM") as noted in Unocal's application, has been'brought to the surface" in conjunction with conventional oil and gas production. As you know, NORM waste occurs as scale or sediment in production tubing and fittings. The AOGCC has written to oil companies that it considers NORM waste to be a Class II substance and eligible for injection into a Class II disposal well. Given the space limitations on the offshore platforms, those tubulars and pipes (as well as from onshore facilities) will most likely be taken to locations offsite of the production facilities to have their pipe scale removed and temporarily stored in drums prior to disposal in the injection well. (Hence, the wastes came indirectly from E & P facilities.) We anticipate the pipe scale coming from three types of storage locations: One existing storage location is Marathon's Nikiski warehouse where pipe scale is stored in drums awaiting disposal in this injection well. A second source will be new pipe scale and sludges with NORM. The sources of the sludges with NORM will consist primarily of treatment vessels for produced water "brought to the surface" in which the NORM sludges settle out. These treatment vessels will be located on the offshore production platforms and. at the onshore production facilities prior to the LACT meter where ownership and change of custody of the product occurs. A third source providing pipe scale that originally had been "brought to the surface" are the service facilities that store tubulars and pipes, such as Arctic Pipe Inspections near Kenai. The tubulars and pipes are stored on storage racks. The pipe scale (as ." Letter to Alaska Oil aas Conservation Commission°; ~~ ~ F ~ ra,' July 10, 1995 ~,::.: ~~, a~ ~~ % ~. Page 3 of 4 Z 1 ,9 fira~~~r_ well as old, non-hazardous, pipe dope used to seal pipe joints) may fall out of the ends and fall to the soil and gravel; other pipe scale from these locations result from pipe cleanings. This pipe scale and pipe dope, some mixed with soil, would be put in drums and disposed in this injection well. Of course, dry pipe scale (and other dry E & P Exempt Waste such as soil), in order to be injected downhole, must have water added to the waste to create a slurry. The sources of this water will include produced water, fresh water from local wells, and/or rain water found within containment dikes at production facilities, such as Trading Bay Production Facility. The rainwater would be considered an E & P Exempt Waste. 2. Besides pipe scale, other wastes to be disposed in the injection well includes rinsate from rinsing drums used to store E & P Wastes, such as crude oil condensate rags, tank sludges, glycol from contactors, etc. 3. Another waste would be gas separation wastes, including wastes which may have come into contact with glycol-based dehydration compounds, arising from operations necessary in the oil and gas production process. Dehydration vessels, such as contactor towers, have a potential for glycol carryover. 4. The equipment wash water specifically mentioned in the Injection Permit will be fresh wash water from local wells since produced water would have salt that would obviously cause corrosion problems on the equipment. 5. Other wastes to be disposed in the injection well are mixtures of E & P Exempt Waste and non-hazardous solid waste or media, such as soil and organic materials which have been contaminated by spills of produced fluids, production waste, pipe scale with NORM or solvent used to clean pipe dope from the threads, or contaminated rainwater from secondary containment sites used for temporary storage of such E & P Exempt Wastes. These mixtures of E & P Exempt Waste and solid wastes which are not RCRA .Subtitle C hazardous wastes would be allowed to be injected since they are equivalent to "hydrocarbon- bearing soil" which EPA specifically listed as an E & P Exempt Waste in its July 6, 1988 Regulatory Determination. 6. Stormwater in contact with secondary containment areas for E & P Exempt Waste storage areas and production equipment, onshore reserve pits, and production pads. The above list of anticipated wastes to be disposed of in the injection well is not all- inclusive, Marathon may inject other wastes determined by U.S. EPA to be RCRA E & P Exempt Wastes. `: ~.. Letter to Alaska Oil a~Gas Conservation Commission July 10, 1995 Page 4 of 4 Request for AOGCC Concurrence It is our view that the above described proposed waste disposals are all legally permitted under the above referenced AOGCC permit. Marathon would appreciate a letter from AOGCC concurring that the above described waste maybe legally disposed in the injection well. Marathon would appreciate a response as soon as possible so that it may use the injection well for all of the above described E & P Wastes quickly and productively before the summer/fall season is over. Our plans are to begin injecting current waste on and after July 24, 1995, beginning with the waste that is expressly permitted under the Permit. Obviously, we would like to maximize our use of it this season since injection wells are among the most envi.*-onmentally protective disposal methods available. If you have any questions, please feel free to call me at 907/564-6372. Marathon would appreciate your prompt review of this matter, preferably before July 24, 1995. Sincerely, ~n ~-. ~.. ., _ J~~ _~_.,/~ ~~ °f~.-- -~" Stephanie S. Olson '~~'~~~~ SSO:WLW:ww Doc. 48683.05 cc Mr. John Betia, Union Oil of California, Anchorage ~3 Unocal Energy Reso Division Unocal Corporation 909 West 9th Avenue, P. ox 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL Health, Environmental, Safety Alaska Business Unit Dear Mr. Johnston: October 10, 1994 Mr. David W. Johnston Chairman, AOGCC 3001 Porcupine Dr. Anchorage, AK 99501-3192 Request for Class II Disposal Well Kenai Gas Field Well KU 11-17 Enclosed are the additional two copies of the above referenced document you requested. If you require any additional information please feel free to contact us immediately. Very truly yours, ccm Enc. ~ ~~y~~ Cathy McMenamy ~J U HES Secretary c~.~~ E° ~.E C ~ ~ X994 p ~ ~mm;ss~o~ A~dska ~-~ & An~h flag? oc~~.c~ ~~~ Y~1 o C. CIRS ~a~, Neaith. Eaviror.mentai. Safety A~asKa Business Unr P q a 3s P X05 ~ S 1° G o S 3 ~s P X05 3~5 P 9os (J~ 33S ~s~ 1ST iS~ i ~S ~0~ ~~x Unocal Energy Res s Division Unocal Corporation 909 West 9th Avenue. FO. Box 196247 Anchorage, Alaska 99519-6247 Telephone X907) 276-7600 CAL ~b RECEIV ~~ pC1' 12 1994 At~~ Di- & Gas Cons. CommissMon Anchora~~ Dear Mr. Johnston: October 3, 1994 -~. `~'~` ~~ Mr. David W. Johnston Chairman, AOGCC 3001 Porcupine Dr. Anchorage, Alaska 99501-3192 Request for Class II Disposal Well Kenai Gas Field Well KU 11-17 Union Oil Company of California (Unocal) formally requests permission to dispose of non- hazardous oil field wastes by deep-hole injection into KU 11-17, Kenai Gas Field. Unocal requests permission to inject both solid (in slurry form) and fluid wastes that have been generated directly from normal drilling and production operations into KU 11-17. Currently, as required by CFR 147.102(b) (1) (C), there is a exemption for aquifers below 1300 feet within the Kenai Gas Field boundary, and one-quarter mile beyond. This exemption fulfills the requirements for Class II injection activities. In addition, data is attached to this letter which fulfills informational requirements of 20 AAC 25.252, for the State of Alaska's Oil and Gas Conservation Commission (AOGCC). The primary purpose for the proposed injection well at KU 11-17 will be for disposal of production fluids. In September of 1993, Unocal lost the use of disposal well KU 14-4. The 14-4 well was used to dispose of more than 30,000 cubic yards of drilling muds (500,000 barrels of fluids) from KGF and CLU. The disposal program included the injection of muds and cuttings from a number of open reserve pits within the KGF and CLU Gas Fields. A plug and abandon (P&A) program is currently underway for the KU 14-4 well. Due to the discontinuation of KU 14-4 the field relies on only one disposal well, WD-1. Furthermore, it is becoming increasingly difficult to dispose of fluids in this remaining well. In order to continue optimal operation of the Kenai and Cannery Loop Gas Fields it is necessary to select another disposal well to replace KU 14-4. Attached are several documents that provide information as required by 20 AAC 25.252. Geologic information, reservoir data, and the Sundry Notice are included. KU 11-17 passed a Mechanical Integrity Test (M{T) in June of 1994. i ~ Mr. Johnstone, AOGCC 10/03/94 Page 2 If you have any questions concerning this request, please contact me at 263-7615. Thank you for you consideration on this matter. Respectfully, ,, -, , ,; ~ , ~~ Bruce St. Pierre Environmental Scientist attachments BWS/ cc: J. Dygas, BLM (w/attachments) Carri Rustad, Marathon (w/attachments) Margaret Brown, CIRI (wjattachments) Jim Segura, Salmatof, Inc. (w/attachments) J. Beitia/File (V1/DI 11-17) (w/attachments) D. Whitacre ,81NS Reading File RECEIV'E'D OCT 12 1994 pa~g~, qi1 & Gas Cons. Commission Anchora~q : i TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of Application ) For Well Conversion for Union Oil ) Company of California for Application ) of a Class II Disposal Well as Required ) by 20 AAC 25.252 ) STATE OF ALASKA ) ss. THIRD JUDICIAL DISTRICT ) AFFIDAVIT OF BRUCE W. ST. PIERRE Bruce W. St. Pierre, being first duly sworn, upon oath, disposes and states as follows: My name is Bruce W. St. Pierre. I am over 19 years old and have personal knowledge of the matters set forth herein. I am an Environmental Scientist for the well operator, Union Oil Company of California (UNOCAL). 3. Pursuant to 20 AAC 25.252(c), UNOCAL, the well operator, prepared an Application For Sundry Approvals, proposing to convert anon-producing gas well into a Class II fluids disposal well. A copy of this application is attached. 4. On October 4, 1994, pursuant to 20 AAC 25.252(c), UNOCAL sent a copy of said application registered mail to the last known address of each owner and operator within a one-quarter mile radius of KU 11-17 surface location and has notified the appropriate departments within UNOCAL. Subscribed and sworn to this 4th day of October, 1994. Bruce W. St. Pierre pCT 12 1994 STATE OF ALASKA ) ss. THIRD JUDICIAL DISTRICT ) 1~aska Oil & Gas Dons. Commission Anchaa~a The foregoing instrument was acknowledged before me this 4th da of October, 1994 by Bruce W. St. Pierre. _~ OFFICIAL SEAL ~,r State of Alaska Notary Public, State of Alas a NOTARY PUBLIC Roxanne M. Sinz My Commission Expiresr ~ / ~ ~' 7 '-fy Ccmmission Expires August 1,1997 STATE OF ALASKA A OIL AND GAS CONSERVATION COMM ON APPLlCATiON FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation shutdovun , Re-enter suspended well ~ Convert to After casing _ Repair weu _ Plugging _ Time extension , Stimulate _ Clas S I I Change approved program ~ Fu11 tubing _ Variance _ Perforate ^ Other ~. 2.:ti'ame of Cgerator 5. Type of Welt: 6. Datum elevaUOn (DF or KB) n of California L'NOCA Development _ lor t ) E KB 85' MSL feet 3. Adcress ory _ xp a Stratigrapnic _ 7. Unit or Property name PO Box 196247, Anchora e, AK 99519-624 serviced Kenai Unit 4 Location ofweilatsurface 768'5 & 631'W of NE corner, Sec. 18, T4N, 8. Well number KU 11-17 R11W S M . . "~? *op of producUVe interval 9. Permit number j (Class II Disposal Well) 81-176 i ~,t effectwe aeq'.r 10. API number 50- 133-20349 At total depth 31'N & 1385'E of SW corner, Sec. 8, T4N, R11W, S.M. 11. FieidlPool Kenai Gas Field i 12. Present wel! ccndiUOn summary ~ ;Dial deotn: measured feet Plugs (measured) true vertical feet ~ect,ve aepth: mmeasured feet Junk (measured) ~ true vertical feet 1 i i ~as~ng Length Size Cemented Measured depth True vertical depth ~ structural Conductor Surface ntermediate (See original Sundry Approval) ProducUOn ~;ner Perforation depth: measured i I R~cE~vEa true vertical OCT 12 1994 Tubing (size, grade. aria measured depth) Alaska Oil & Gas Cons. Commission Packers and SSSV (type and measured depth) i AtlCho~azJ~l 13..<;ttachments Description summary of proposal ~ Detailed operations program _ BOP sketch _. Convert to a Class II disposal well. 14. Estimated date for commencing operation 15. Status of well classification as: Nov. 1, 1994 16. If proposal was verbally approved Oil -_ Gas _ Suspended _ Name of approver Date approved Service Class II Disposal 17. I hereby certify that the foregoing is true and Correct to the best of my knowledge. ~- ~ . Signed ' ~~~~~ L/. ~ ~ Title Environmental Scientist pate 10/4/94 Conditions of approval: Notify Commission so representative may witness Approval No. Plug integrity _ BOP Test _ Location clearance _ Mechanical Integrity Test _ Subsequent form required 10- Approved by order of the Commissioner Commissioner Date Form t0-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ! f RESERVOIR INFORMATION KU 11-17 WELL, KENAI GAS FIELD, ALASKA Criteria for choosing a disposal well included: • using a well bore which has no future potential for production, • determining that the well has sufficient disposal capacity into one or both of the already permitted and approved Sterling sands, • checking strata maps to insure substantial vertical confinement, • looking at Cement Bond Logs to insure mechanical integrity, and • adequate tubing size. The well that best fits these criteria is KU 11-17, located on KGF Pad 41-18. This Kenai gas well has no future potential as a producer. The short string died in July of 1993, and the long string in February '93. The short string can be selectively injected into either or both of the B3 and B4 sands. Possible short string injection zones from well 11-17 include 32 feet of the B3 sand (4,465'- 4,497' MD), 150' of the B4 sand (4,522'- 4,586' & 4,614'- 4,700'). Long string injection potential includes 128' of the C1 sand (5,102'- 5,155') & 5,172'- 5,247'). The exemption limit is 1,300' for the Kenai Gas Field, so the proposed interval of injection is well below the specified limits. There are a numerous laterally continuous shale layers above the sands and 173' (4,465'- 4,292') of solid cement bond in the casing annulus directly above the zone. The dual 3 1 /2" strings are of adequate size, and the site is not easily accessible to the public. Fluids planned for injection include produced water from the Kenai Gas Field and Cannery Loop Unit Gas Field. In addition, non-hazardous waste fluids generated by normal drilling and production operations would qualify to be injected down the Class II disposal well. This includes, but is not limited to, slurries of drilling mud, NORM scale, and other exempt drilling and production wastes. Maximum disposal is not expected to exceed 3000 barrels of fluid per day. The surface location is within the Kenai Gas Field Unit, and the working interest is divided among Unocal, Marathon, and Chevron. Land ownership includes Cook Inlet Region, Inc. (CIRI) and Salamatof, Inc. The Bureau of Land Management (BLM) manages the federal lease. All applicable agencies, working interest owners, and land owners will receive a copy of this application. Attachment #1 includes data from the MIT done in June of 1994. Attachment #2 consists of wellbore schematics of the disposal well. Attachment #3 shows the surface location and the approximate bottom hole location in relation to other wells in the vicinity. There are no wells completed in the proposed injection zones within aquarter-mile radius of KU 11-17. RECEIVED OCT 12 1994 ~Jaska Oil & Gas Cons. Commission gnchora;,a f t Attachment #1 O erator Unocal MIT Procedure: Hold orientation meeting Pressure casing to 1,000 psi Hold for 24 hours Record surface casing pressure Results: 6-10-94 1,000 psi 6-11-94 988 psi Casing lost 12 psi in 24 hours. Date 6-10-94 RECEIVED X:W~r~~~ya~a~dv~r~a ~.~ qCT 1 2 1994 ~iaska Oil & Gas Cons. Commission Mchora,~ Mechanical Integi7ty Test Fiefd Pad Well Tyge Kenai Unit 41-18 11-17 Idle v ~ J '. Tl r n'-1c-~~ v ~'i•, n:i y'~IJ - ~~ Y' (11 ~ I';' F Iii ~ ~~~~ i led .. ~ ~~ ~~ ~, r, SIT r~ ~, ,~ ;~'4~1F~ I ~1{~rr~l' I ,i (~ A if f ^ ~.. ~. it I ~,~ ~1 _ --; - 4fi41 - 4661' SQUEEZE PERFS Sgt'd lower B-4 ~~ ~~ - ;; _ ~ i^. ~~ 5103 - 5145' SQUEEZE PERFS lsola~ion Sqt. '' 5160 - 5162' SQUEEZE PEKES fsalation Sqt. "~: I , rr~~~,~~~I + ~~I~ ,~1 , _ rT~, ~,~.~~ LI~US. ~ 1 ~'~~q2r. - ~";~' ' ' ' ~.~' ~'~ r ~'.~~k ~± ~-8G TBG LANG SIRING - ~_0' ~...~" . ~~ ~ . r ~~ ft "~ ~~!) TBG `~HOR1 SIRING 4468 - 4483' PERFS B-3 4528 - 4581' PERFS B-4 5106 - 5152' PERFS C-1 RECE~v ~~ OCT 12 1994 plaska- Oii & Gas Cons. Commission Anchora;,~ u~, TD, S,~ r' i ~' Pools ~an~s: ~~.' ~ 6 - ~ . i,' ~'~j'i~~efP'~, _ ~, ~,~, '641- '661' SCUE~E PERFS Sqz'~ tower B-A 5103 - 5105` SQUEEZE PERFS Isolation Sqz. 5160 - 5162' SQUEEZE PERFS Isolation Sqz. :anal '_~.;~ ' ~I'~ ~nQle ~~ P~rt~: '~I.'~ Qe~S, ,I ~ , + - ~n ll ~ i ,~,_,I,4 ~~,_ -.4r,i„i, ~, _ ~~ I~ I I I ~`? - ^~J48' ~ r° uD Zu9" !D ~+20~ 'ft N-601BG SONG STRING . ~ ' w~ -~ '`it LL~'dC !_' ~~ ,un ~_ _ _. ky - _ ~ ~ ~'U~~ ~'~~. .-, ~-- _~e -,~~' bt~~~ U~.I ~1 ~~x~~ 4468 - 4483' PERFS B-3 ~ - ~ _- ~ ._ ~ _- .jai Pkr. ~ - _ 4528 _ _ 581 PEKES B 4 ~~ ~~ , ,, bra;; ~~ ; ~' ~' _~r ,~. ~i _ ~ - -~ - ~ A. ~~ ' ',1( -~fl I9Ai(1111n llr I ~laa9 - ~~+99' ~'JCATOR Jt~iPIT i ~ ~ ~ _-ni: ~ .ern p nr !r_. ~_,. ~ :' f - ~;' _ ,~ for ',.U~ "JJ~. ~ ~ ~6~8 ~ X41' MUl~SHOE B~k;er Bull Nose E~fry Guide 5106 - .5152` PEKES C-1 RECEIVED OCT 12 1994 - ~;,1' r ~~" ~5 µ~.00~/`f1 N-80 PROD CSG h~f' ~~ f 1- ~~~,1 S~iGE Alaska Oil & Gas Cons. Commission Anchors,.] T ~;' ~ I~~S We~~ ~ „~ ~~, i Paais/`Sands: ~~.1 & ~6 I ~ i ~^r, ~Gmpl~>;~d ~iyy~/~~% 11 ~~n~l (,I~~ rigid ~~•nQI~ i~ FPrtS: ~.~ ~~(~S. ~-'.A * y~A't~ir~ :V1~1. 1'V+~'SJ~~~J ~•r!~ I'1YU ~v + ~~ ~ v~~-I„il~+ ~~~ngef. ^~~r~.i ~~rl T ~ ~, I ~ I '1 ! ~ '~ - X520' x.500" ~D 9.`?0~/`ff N-80 TBG SNQRI SIRING ~~ I ~ ~ ~J1 - ~J4~ "iC'JU:;,"u' ' X551- ~~51' JISINT Ee<i Hard :~ate~Y pub ;~ - ~ ~. ~ _ _ ~~ Huai rKr. :~ ~~ ~ ~ i,r2 ~;t '~n'~EE ~`'~'v1 Faker i?iescoplog Swivel Sub '' 4468 - 4483' PERFS B-3 _ _ 4431 - ~~4' ~Lt~E Ijil~ ,Cr•'i~jDe(1 b~2~l93~ 4528 - 4581' PERFS B-4 ~~ 4641- 4661' SQUEEZE PERFS Sgt'd EOw2f B-4 ~' ~ ~ ' ~ ~;? - ~~DS' ,iIS"NI Left H7r~~ a~ety Sib -,n _ ,~~r,i ; ~ftil1'~If;'•'!-'GIG , i'~ r ~ ~ ~ -. ,. __~ ~.~~,~,~„ ~,,, , ~~ _.,~ ,~,N ~ ~^e y ' i ~~ i 'i '~ ~ I I it ~ ji 5103 - 5105' SQUEEZE PERFS Isolation Sqz. j~ ! 5106 - 5152' PERFS C-1 5160 - 5162` SQUEEZE PERFS lsolalion Sqz. RECEIVE OCT 1 2 1994 IS - E~~i' q ~~S" ~,D 4?.00#~f1 N-80 PROi) CSG ~.Iaska Oii & Gas Cons. Commission 5d 1 I - -;~ 1' ~ SN4E I ! Anchors; n8T0. ,,.-;~ u; 5311' Gas dell Pools~Sa~ds; #~,1 & ~G ~ 'T` TMO 4390 'TMD 7290 S U-M KDU-2 (2l-81 ~` a , T M o X0,620 ;' ~: Orig. Hole ~s KdU-4 ~~ TMD 5540 (J 8 A) t~ ~~ 1 U-M 7 i KBU-13-8 8 U- M ~ h TMO 8770 KDU-4 RD (13-7) ~ U-M Mo lo,e I o ~KU-43-7 TMD 5 700 J- M / KUN-I (14X-8) T / "-~- T M D 14, 7 21 4 ~ ~ 4 '~ KU-~1-17 .. 2 _ ~- - ~~~ K~>. l l N ~ T/STERLING GAS SOSr~' 9.H.L. _ "~- 5T00~ TMO R.H. ,o _ _ ^ 4300 MD 5000 TV D 53 4f-i8 (KUH-i) 3725' vD T, (~,~R~ RECERVEQ OCR 12 1994 ~ 8 Alaska Oil & Gas Cons. Commission ~ ~ Anchora. /-FTi ,4 ~ f-/~ Yl ~ N 7` 3 U-M ~~~I K U- 44-18 Alaska District TMD 6020 0 500 I Ooo K E N A I GAS F I E L D PROPOSED FEET , WELL. LOCATtE?N KU-2t-IT`~ O N na ~ o ~1 N _~ 1 ~~ -~ ~1 1 \~ ` .d~ 11 ~ i ~\. .111~~ .r~.,u. •trr.N ,.~.. m. .m r r. r r ~..~° ~,.. . limns of grovel !iB c• I . Qreu. s. e. . O nut} 7 °~•„ > 0 r•in,on it )~~a e1{~ r•t,fu,ofr ~~ ( , r,,• \ ~•~~, I ~ .ii 9u. 21 7 yon ..JJ((~~ •~ arf nfr >s f•l,f~6,gf 69 '. n/ C I_ o r" i ~i fp~~ 07 Q Wuler Well .-rrf,~rr •. ~( ~ r.1d f.9n ~~ V~/'°~° ~ r ~~ w(1~ i •. Ilf,lil.11 ~r l~~°I11•~I not \Jtl d• /Of~ ' • t,1ff 9Q 00 n tr./NO Yrfr,-n w KU. ei-Ib "'r""' .',o III I•i.fff,l•~I r-2 rMEl~r - f t -~ S+rs..~~i bruU '~ tay [Nleire ,` eYrY. •"ri „t, nf,mn N ?~ ` n• ~rBU 17-8 ~~ I IW 9,f a Sump Av. depfA = 63' rE.l '~ ••n•sEau r• t,vfeAe. o M t'ry,nuY "ern ~ ~~ ~vu q~~ 1 AS~~QUB~~6 ~QJ~P~N/~S7 ~~~a~~o~~ ~ca~ ~o~o~ a r W V {..L- ~ •~ ~ ~ -+- /`~ ~~~ I ~Ih" ~- e-- i _ ~~'7T~T F- i-ir - -- ~, w ee'u'zr,• --- W :rfAV.b is`9.r3 ~~isff,neu o e t' o ~:~o o.f9• • r• t.9sf,fa r t.r i rw r~ e, fe r.r rr~-o er>, .• i~ff6~i00 ___ 0 q .~ ~~ ~' ~ Z `~ a~ F- " U °~ Q r•f,ff6/xq ~,~,f,,.i~a U ,~ ,..~ >< ix•Ar~ ~ . ~ 41-I9 V I' it Y n Y I ~l , i i ~ •M VICINITY MAP SCALE I°= 1 mile I.EGENO ANO NOTES ~1 Found brace cop Inonumenl • Sef !/2" r 24° sfaN rebac o Powr poN wilA owrMOd uvula. ® Eeielinq well chrislmas Ire Inside small sleet buBJinq. el Fourd2"pyCplpeoras nsMed(Monilalnp Wells). Relrrelrts slalom b Mean Sao LevN =0.0 la elevolions Brown. Elevaliom have been reviud N coMorm wilA Me orlglnol well cNla Inv KU I I - I7 and Mann Sao L evN Oolum of 0 DO (7- 23- d5 ). All bearings art grid ucepfnafed olAerwisa. Basis of Coadinolu ie USC.9GS. iri Slalion AUOflY In A.S.B Iona 4. Arnopa converpana of poln/s eAown - I° 04.58" AUORr Lat. 60' 30. 50.559"N Lang. ISI' 16.37.443"W x= zeq,ecsls r = z,3ez,as.4z ENvalione of UN lap d pipe fa msnilalny welN wn laeen with carer Wf w span. Addle K.U. 33-7 _ _ _ _ __. _ _ _._ __-_ 4- I -BB AdAk ~~ UM 2 - 4 - f10 __ Addw x e r coordllrofw ro:,n lowflon,-! I I = foie _ AOded MoMlwht2 NrR Md~tpdoNd _ 7- Y3: 14 _ Rerlpl Elw. al fbuM M_onLlaNr~ WNl _ ~ D _ j`. ~ AaNd Monllorle wMb ~ ~ _ (_y. tl upeofd io _ 2~. ea REVISIONS OATE KENAI GAS FIELD PAD 41-18 AS-~UILY SURVEY UNOCAL R0 8dc 190217 AnclNrage, AIwW 99502-0 217 Surrere0 br ~ MtLANE arld ASSOCIATES, INC 8ddofae, AK. 9fHi69 DATE Of BURVEY I fiCALE ~ BHEET ' ~ ~ ° rrt ~' ~ ~ ` ~ o ~ rn ~ C? ~ N ^ ~ ~ ~ ~ cD ~e y.~ { ~ • ~ ~ .~ ~~~ \ PRpp r ')II~I~ I ' I t ~' ~~; r~croo. w1- rt II aulr~ . ~, I I i I I I i In ~~: I" I i I i I 1 ~' ~` I I f ~I~' _ _- ~ - _-" i 1 __~ I - -~ S/TF 4/-I r - ~- _ _ _ _.._ ..._ _..~ .5/TF 4/- /8 i I c A-a2s 142 ~ 25eoe~. j CIRI SUBSURFACE SALAMANTOF VILLAGE SURFACE EN7fRL' LEASE ' ~! 1 ,J' ' E'RO(1 J E tJU I F' t / • t ADL-2233C I ' 1864,72ec. CIRI Surlece 8 Subsurface Entire Lens•~ ~ .r , t l r 1 -- ----__ -~ ~~ STATE r ~ ~ BORO SEL. APLN. 66708 ' , ~ ` i :~ ~.~ S!~ ~E 41 1 g ~ ~,,a ~R(l[t. f OUIP {~1 t not-324599 8 4 0 ~ •I",y • . > elA ~ ~ ~ elm ell a elr ell ew L ~ e c. PJ, v i N _ ~ • GEOLOGIC FORMATION SIIMMARY RII 11-17 WELL, RENAI GAS FIELD, ALASKA A subsurface evaluation was conducted to determine the stratigraphic relationship of the freshwater aquifers and the proposed disposal well sands in the Kenai Gas Field. Results and Conclusions: Plate 1 is a north-south stratigraphic cross-section showing the lateral continuity of the impermeable shale intervals. These shale intervals act as upper and lower confining impermeable units in the sand-rich Sterling Formation. The shales vary in thickness from three to 40 feet. The data available is conclusive that the shales are widespread and prevent vertical fluid communication between sandstones. Plate 1 also shows the stratigraphic relationship of the freshwater aquifers and impermeable claystone intervals in the Pleistocene strata overlying the Sterling Formation. These freshwater aquifers are generally fluvial channel sands bounded by lacustrine claystones. A major unconformity lies at the base of the Pleistocene strata (top Pliocene Sterling Formation). This unconformity also acts as a barrier between the freshwater zone and the more highly saline Sterling Formation sands. The sediments below the base of the glacial deposits are in the upper and middle part of the Sterling Formation. These sediments are sands, siltstones, shales and occasional thin- bedded coals. The sands are highly unconsolidated and are generally uncemented. Intervals shaded brown on the type log indicate impermeable shale zones. Waste water is currently being injected in the Sterling Formation sands that are colored dark green . R ~ C C ~ V E nCT 1 2 1994 ~-iaska Oii & Gas Cons, Commission Mct-ora~ ~ ryjl~~'y -- - ----- ~ -- - -- -- - - r ~ `T _ ~ - s~.es.r rs3- ! T.. i'-, ~ I' ,A(f~..~,~~L$,rl~•'~.~!-{~y~ ~ .4 _ i ~ _ - ~ r - ;%, -. z° ~-- 6 r „; ~ ~--: `,~ ~'sk jai 4 y _ _ '~-. - ,;'` '~ _ -~. •• - - __ . >< o ~~ ~ _ - _ ~t ~ 7 _ 9 2 0 11 ~~' , 12 a.- ~;~ __ - - -_ ~ - - ~..~r.- ~" ~ .a I ~ ~ -~-~-- y...------ _ _ _-i --------- -s~,., ,- t ' t ~ ~: 1- 2G ~~ 2: 22 ! ` 23 _ '24 ~ i ~ '? -_: i. -, _ ~,..« 8 ( ±~ _ \ i »5 ~ ~. „ .. ' _? 26~ _ psi j i SITE 33-30 I •~~r 1 ' 1 ' \ ~ r~ SITE 43-32 ~ SITE 34-31 I ?anpsng ,~ - ~ 1 .;as ;.P~,~ . ----- - \. ._. a ~. .. ..~. 1 _~.., w.KENAI GAS -FIELD ~ ~ _ ~~. _~~ ~ t _ 1. Gravel ' ~ j ~ ' .~ r Prts . -v _. :~ f , - f • .~. r SITE 14-6 p _ , 1 ©a_ .ti ,_ .. SITE 14-4 ~ _~ . ~ , _ .~ :~ , ~ ~ SITE 41-7 ~ ~ana~~ ~ ~t~. ~~ •1 .~ ~~- ~o __ y ~ . } s ~~ ``;~~~~- - ~ 1 D SITE_41-18 ~ ~~`; °'~"~z,~. ~ ,, /~ - - - ~ - Wit; ~ •~'~~ ~ ~__~ _ ~b~T 121994 - y ~_ ~, .~. _ - ~ -SITE 44-19 r - .- -. _ _. ~~~ _- • f ;} ~ f~iaska Oii & Gas,Cons Commission •`-~r,a,ng. ._ _ .~ _ } ~V { G - ,wry' ai ~.r.n t _ - ~ _ _ 4 22 ~3 .: ~ ~-- ~ _ _~}~ ~<.~,r ~ I _ ,~ `~ / ' _ - : ,'_- ~ - ,~ _ _ ~ ~ - - - _ ~~ N N 0 a~ A~' S y o w ~_ ~~ H O C7 --~ N .~. rn rn_ C r-n Q P `l~`' ~~5 I,~9 Certified Mail Receipt No Insurance Coverage Provided ~~ Do not use for International Mail ~~"°S,.,ES (See R ~sf.rt~~K, everse) Fol P 905 =~35 1,05 Certified Mail Receipt No Insurance Coverage Provided Do not use for International Mail ~:E~~~ (See Reverse) Sent to c~R ~ 1 m~Q~ ~~, 8 T ~- Slfeel No 5 C PO ,Stale 8 ZIP Code ~ K 9 95a Postage Certified Fee Special Delivery Fee Restricted Delivery Fee Return Roceipt Showing to Whom & Date Delivered Return Receip[ Showing to Whorn, Date. 8 Address of Delivery TOIA~ Postage Q 8 Fees a~ PosVnark or Date ... - .. - ... _~ ~r 9 n s ~ ~ ~ i [; ~~ ~~ FJ `~f75 335 1[J4 _ Certified Mail Receipt No Insurance Coverage Provided Do not use for International Mail (See Rever e) _ Sent Slreel 8 No. o L.~Z• .e PO ,State 8 ZIP Code ~,/. a ~ ~~ Certified Fee Special Delivery Fee Restricted Delivery Fee ~ Return Receipt Showing pr to Whom & Date Delivered O] _ Retwn Receipt Showing 1o Wham, ~ Dale, R Address of Delivery C ~ TOTAL Postage p 8 Fees ~ Postmark or D:de M E o lL a X10 1- ~, , ; fJ r ~i J J =~ ~J .~ J f Certified Mail Receipt ~~ No Insurance (;overage Prcwided '" Do not use for International Mail ~~ ~s,E° Rs„ (See Reversel _. .`lent ` ~ ---.. _.-._ 1~ ~ yGcc^a ~a d --- _ -_ Slreel R Nu PO , Stale R 21P Code yi ,~ e. ~~ ~ ~~~ I Postage --~---1._. _ candied Fee - -' ----- Special Uehvery Fee --- Restricted Dt,hvary Fee --~- -~----_"- Retum Receipt Showing -- ° to Whom 8 Uale Delivered Q] Return Receipt Showing to Whorn ---- C Dale. R Address of Delivery J ~ TOTAI. Postage ~ R Fees ~ Postmark or Dale M E o (n a -; .L' r' q _, _ Certified Mail Receipt No Insurance' Coverage Provided ~~ Do not usE~ fot International Mail ien sacs (Cj88 RCVE?ISB~_-__-___. _..-.- ~,1nt to ~1, .,,,, ~ I I'~1_ ~~ ~Y~--- ~treel R No • " IP C . , d r ; I R PO . SUtie f~ ~ Q 4S L. ry ~ ~ ~ r '_~` ~~~~t ~ ~ ~ ` -' y sla ~~ !/ f ~ - g Pu __ _, Cerldled Fee -------- Specla~Fee _-_--- ~ ReshICIL'd DetlVf;ly Ft;l;~ ..._- _ Return Receipt Showmy- ° to Whom R Dala Delivered __-------- 01 Q, Return Receipt :ihowmd to hom, ~ Date. R Address of Delivery c ~ TOTAL Postage ~ R Fees r ~ Poslmaik nr Dale E 0 LL Cn a W m c.~ ~ ~ ~ c ~"" N U `o W ~- ~ V ~-- `-' a W cJ °~ cY • r.~ Cl ~"1 ~ .~ ~ L 5 P 9CiS 3.35 1D4 P ~D5 a ~ ; 1,57 ~2 r r Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of Union Oil Company of California (Unocal) for an order allowing the underground disposal of Class II fluids by injection into Kenai Unit well 11-17 in the Kenai Gas Field. Unocal, by letter dated October 3, 1994, has requested the Alaska Oil And Gas Conservation Commission to issue an order in conformance with 20 AAC 25.252. The order would authorize the disposal of Class II fluids by injection into the Sterling Formation in well KU 11-17 at the Kenai Gas Field on the Kenai Peninsula in Southcentral Alaska. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 p.m. October 28, 1994, with the Alaska Oil and Gas Conservation Commission (hereinafter the Commission), 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 a.m. on November 18, 1994, in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433, after October 28, 1994. If no protest is filed, the Commission will consider the issuance of the order without a hearing. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Diana Fleck at 279-1433 no later than November 11, 1994. ~~ Russell A. Douglass, Commissioner Alaska Oil and Gas Conservation Commission Published October 13, 1994 STATE OF ALASKA ADVERTISING ORDER NO. ADVERTISING ORDER AQ. 02-5-14-017 AGENCY CONTACT DATE OF A.O. F AOGCC Diana Fleck 10/12/94 R 3001. Porcupine Drive PHONE M Anchorage AK 99501 (907) 279-1433 , DATES ADVERTISEMENT REQUIRED: T 10/19/94 ~ Star Publishing Company ~ 16941 N EagleeRiver Loop Rd. e Eagle River AK 99577-7499 L , I SPECIAL INSTRUCTIONS: H E R AFFIDAVIT OF PUBLICATION UNITED STATES OF AMERICA .R ._ ___~ T --T.•- .-~ `- 960-Public .Hearing STATE OF ss INVOICE MU 'UST REFERENCE d ~ THE ADVER NOTICE OF PUBUt:`HEARING ` ~~""~ DIVISION. A CERTIFIEt ~ srAtloFnLASKA Au-sw- OIL AND GAS )F PUBLICATION MUST BE Sl CONSERAVATION COMMISSION ' CE. BEFORE ME, THE UNDERSIGNED, A NOTARY PUBLIC THIS DAY - Re:TheapplicationofllnbnOilCom- parry of Cahfomia (UnocaQ for an -"" orderalbwingtheundergrounddts- -~ ~ PERSONALLY APPEARED Y ~ 1 , L,je}~Pi%WHO, q'~p posaloiClassllfluidsbylmjeciion iN HERE. into Kenai Unk well 11-17 in the Kenai Oas Field. BEING FIRST DULY SWORN, ACCORDING TO LAW, SAYS THAT 1994 has'reyqu sled tae Al~asok~a Oil And 0as Conservation Commission to "issueanorderintx~tomlancewith20 HE/SHE IS THE CJ? t . O F ~,Qb__S~L~ ~ AAC 25.252. The order would autho- dze the disposal of Class 11 fluids by PUBLISHED AT 1/ IN SAID DIVISION injection into the Sterling Formation in wen KU ti-17 at1heKenaiGasField on the Kenai Peninsula in Souttx:entral .Alaska. , AND STATE OF AND THAT THE ApersonwhomaybeharmedHthe .requested order is issued may file a written `> protest prior to 4:00 p.m. i ADVERTISEMENT, OF WHICH THE ANNEXED IS A TRUE COPY, WAS ~ october28,1s94,withtheAtaskaoil i and f3as Conservation Commission PUBLISHED IN SAID PUBLICATION ON THE ~ DAY OF (hereinafter the Commission), 3001 Porcupine Drive, Anchorage, Alaska 99501 h d t i th ~~,,\\ ~ , an reques ear a ng on e matter; N'ihe protest is timely, filed and raises a substantial end material ,XU `~ 19 ,AND THEREAFTER FOR ~. Issue oruclai to,'the' Commissbn's determination, a hearing on t he mafter CONSECUTIVE DAYS, THE LAST PUBLICATION APPEARING ON THE will be held at the above address at 9:0o a.m~ on November ie,1994, in ' Q ~ n 11~ ~ ~„ J C L DAY OF L/P~ ~f ' conformance with 20 AAC 25.540. If a hearing 3 is io ~b9 held, interested arties ma COnflrmthisb callin the' A - 19 ~ AND THAT THE ' g y p Commlelson'soflica(907~279-1433 , afleol~clober 28,' 1994r If no protest RATE CHARGED THEREON IS NOT IN EXCESS OF THE RATE Isflled,theCommissbnwiilconskler'. the issuerlce of th9 ortler without a hearing. CHAR D PRIVATE INDI DU S. If you are a person with a disability who mayneedaspeaaimodif'~cation in order to comment or io-attend the public hearing, please contact Diana: Fleck at 279-1433 no later ttian' SUBSCRIBED AND SWORN TO BEFORE ME November 11,1994. '' RusseNA.Douglass,Cammisstoner .~ ,/ THISr~Z AY OF ~~~ 19~ Alaska oil and Gas Conservation A ~ in -0 1 O-025 14 PubNshed: October 18,1994. NOTA PUBLIC FOR STATE OF MY COMMISSION EXPIRES Q-S- 9~ 02.901 (Rev. 6.85) PUBLISHER 911854 / STOF 0330 AO-02514016 $59.85 AFFIDAVIT OF P UBLICATION STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) SS. Eva M Kaufmann being first duly sworn on oath deposes and says that she is the Advertising Representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on: October 13, ,1994 and that .such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. signed-`~-~ ' ~~ Eva M. Kaufmann ~ Classified Advertising Rep. 257-4296 Notice o ~ u 1 c Hearin STATE'OF AI.q~KA 1` Alaska Oil s11d , as 1; ;. 1 `4 Conservatlen~tom, isslon ~Rei~The application of"Union'. 1;011 Comppany of ,California ' (Unocaq Fot an older-allowing !, t ass Iltlflu ds by ~ led~on Into Kenai -Unit well 1L17 in the Kenai ~Gas~Field.~y "' ,Unocal; by letter dafed Octo• •Alaskel0il~and Ga4 Conserves t(on Commission to "Issue an :Order In conformance<:with 20 AAC 25.252.-She brder ylquld euthorize he disposal of Class Sterlling Fo matron ~ ~well'KU 1riJ7 aYthe Kenai Gas Field On 'the KenalSPenlnsula~in.Squth• rehtral Alaska. z A person who maY~be harm. ed it -The 're~ue4lOd order is ~' Issued may 9i e s written pro- test prlo,,((}} to 4:00 P;m+ Octoper +.andl GaaWCgns rvationkCOmil mission (hereinafter. the'CQm' missionlr ~30b1:•~PorcuPlne Drive;r~ Anchorager° 'Alaska ;99501, and requests hearing on ?ihe :matter. If the protest ; is taimelY tiled and raises a~sub< ,st2ntial and materiah+issve •determi etione a bearing oe =the matter will be held atthe dabove address at 9:OD a:m•'on~ ;November 19, 1994, in confor•' <mance with 20'AAC 25.5• If a' ~~hearfa9`I3 to be held, interesf•, ed parties may confirm this by! ~~ calling the Commission's offkea (907),274 1433, aft r October, 26f„ ;199a.'If no protlt:l~constder the`. Commission w[ out a', .Issuance of the.order Wttt~ hearing. ` • ., "rson with,. a' • If you are a pe dlsabiNty who , may new a' spedef moditicatlon In prdef, to comments or° 40 'attend the public;hearing, Please contact Diana Fleck 'at 279~1433~~ Iater than November n; , 75/Russell A. DAlaska Oil °, '';Commissioner, '',and Gas Conservation `Commission Pub~`Odober':1;~, 1944 ,„_.___ Subscribed and sJwo to bef e me this ...!. da of Y .. .~K~!L, 1994 ~a~~. .. ~ ........... . Notary 'c in and for the Sta of Alaska. Third Division Anchorage, Alaska MY COMIvIISSION EXPIRES: MY COMMISSION EXPIkFS ........DULY 24... )P~4 ............. 19...... ~1 • ~ APPLICATION for INJECTION KENAI GAS FIELD UNIT, WELL KU 11-17 KENAI, ALASKA Submitted by; Unocal PO Box 196247 Anchorage. Alaska 99519-5247 October 5, 1994 Unocal Energy Resou Division Unocal Corporation 909 West 9th Avenue, ox 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 • UNOCAL 76 Health, Environmental, Safety October 3, 1994 Alaska Business Unit Mr. David W. Johnston Chairman, AOGCC 3001 Porcupine Dr. Anchorage, Alaska 99501-3192 Request for Class II Disposal Well Kenai Gas Field Well KU 11-17 Dear Mr. Johnston: Union Oil Company of California (Unocal) formally requests permission to dispose of non- hazardous oil field wastes by deep-hole injection into KU 11-17, Kenai Gas Field. Unocal requests permission to inject both solid (in slurry form) and fluid wastes that have been generated directly from normal drilling and production operations into KU 11-17. Currently, as required by CFR 147.102(b) (1) (C), there is a exemption for aquifers below 1300 feet within the Kenai Gas Field boundary, and one-quarter mile beyond. This exemption fulfills the requirements for Class II injection activities. In addition, data is attached to this letter which fulfills informational requirements of 20 AAC 25.252, for the State of Alaska's Oil and Gas Conservation Commission (AOGCC). The primary purpose for the proposed injection well at KU 11-17 will be for disposal of production fluids. In September of 1993, Unocal lost the use of disposal well KU 14-4. The 14-4 well was used to dispose of more than 30,000 cubic yards of drilling muds (500,000 barrels of fluids) from KGF and CLU. The disposal program included the injection of muds and cuttings from a number of open reserve pits within .the KGF and CLU Gas Fields. A plug and abandon (P&A) program is currently underway for the KU 14-4 well. Due to the discontinuation of KU 14-4 the field relies on only one disposal well, WD-1. Furthermore, it is becoming increasingly difficult to dispose of fluids in this remaining well. In order to continue optimal operation of the Kenai and Cannery Loop Gas Fields it is necessary to select another disposal well to replace KU 14-4. Attached are several documents that provide information as required by 20 AAC 25.252. Geologic information, reservoir data, and the Sundry Notice are included. KU 11-17 passed a Mechanical Integrity Test (MIT) in June of 1994. EIVEq ~, i °~ 7 ~~.~~'~~ still ~ has Cn~:s. C^rnrrl~sion h, ~ ~ Mr. Johnstone, AOGCC 10/03/94 Page 2 If you have any questions concerning this request, please contact me at 263-7615. Thank you for you consideration on this matter. Respectfully, Bruce St. Pierre .Environmental Scientist attachments BWS/ cc: J. Dygas, BLM (w/attachments) Carri Rustad, Marathon (w/attachments) Margaret Brown, CIRI (w/attachments) Jim Segura, Salmatof, Inc. (w/attachments) J. Beitia/File (V1ID1 11-17) (w/attachments) D. Whitacre BWS Reading File ~~~ V L~~ ,n,,„~.. _ ~ i~~ .~ ., . ,, ~~~~ ~,~;~ Go.fs ~smmissian #~nchor~~;<< • ~ ~ • KENAI GAS FIELD WELL #11-17 APPLICATION FOR UNDERGROUND INJECTION Union Oil Company of California, dba Unocal, requests that the Commission issue an disposal injection order authorizing KU 11-17 to be used as a Class II disposal well in accordance with 20 AAC 25.252. Section B contains a regional map showing the location of the Kenai Gas Field Unit and the associated drilling pads. KU 11-17 is located on KGF 41-18 pad. 20 AAC 25.252(0)(1) Section B contains a plat showing the location of the proposed disposal well. There are no production wells that penetrate the injection zone within aone-quarter mile spherical radius of the proposed disposal well. KUH-1 is an adjacent well drilled straight down to approximately 9,000 feet it then kicks out to a bottom hole of 14,721 TMD to the northeast. The spacing is more than 6,000 feet between KUH-1 and KU 11-17 at the proposed injection zones, well above the quarter mile requirement. A cement bond log is provide for KU 11-17 in Section G. 20 AAC 25.252 (c) (2) The surface location is within the Kenai Gas Field Unit and the working interest is divided among Unocal, Marathon, and Chevron. Land ownership includes Cook Inlet Region, Inc (CIRI) and Salamatof, Inc.. The Bureau of Land Management (BLM) manages the federal • lease. Section A includes copies of certified mail receipts for all surface owners and operators with 1 /4 mile radius of the proposed well. 20 AAC 25.252(c)(3) Section A contains an affidavit showing that the operators and surface owners have been supplied a copy of this application. 20 AAC 25.252(0)(4) Section E contains geological information for the Kenai Gas Field Unit. An fresh-water exemption zone has been established for the KGF Unit at 1,300 feet. The geologic cross section runs north to south with an inclusion for the disposal well at KU 14-4. 20 AAC 25.252(c)(5) Section G contains a cement bond well log for KGF 11-17. In addition, the geologic cross section in section E has well logs for each well interpreted. 20 AAC 25.252(c)(6) Section C includes schematics of the present condition and proposed injection zone in KU 11-17. On June 10th and 11th, 1994 a mechanical integrity test (MIT) was completed. The casing was pressure tested to 1,000 psi. Section C includes a copy of the report of testing. n U i ~ • 20 AAC 25.252(c)(7) Unocal proposes to inject non-hazardous fluids associated with drilling, production, and workover operations. Such fluids may include, but are not limited to: • Produced Water • Drilling/Completion Fluids • Equipment Washwater • Drilling Mud Slurries • NORM Scale Section D includes water analysis reports for the Kenai Gas Field. There was not a water analysis available for the proposed well but there are analysis provided for WD-1 and KU 14-4. As shown in the two water analysis reports, downhole water quality is very consistent throughout the field. Section D also includes a gas analysis report for KU 11- 17 done in 1986 when the well was a producer. Finally, section D includes a general breakdown of potential injection fluid constituents. This list is not meant to be inclusive, and a Sundry can be submitted if material is proposed to be injected that is not fully defined. All fluids will follow the definition for applicability for Class 11 disposal. Maximum injection rates should not exceed 3000 BPD; average injection rates are estimated to be 50 to 100 BPD. • 20 AAC 25.252(c)(8) Estimated average injection pressure is 1000 psi; estimated maximum injection pressure is 2400 psi. Maximum injection pressure for produced water is not expected to exceed 1300 psi. Average operational injection pressure was determined by evaluating past step-rate tests performed on KU 14-4 and WD-1. Both wells are permitted as Class II disposal wells within the Kenai Gas Field Unit. Section F contains a copy of a step-rate test performed on KU 14-4. The fracture model in section F includes parameters from the WD-1 disposal well. 20 AAC 25.252(c)(9) Section F includes an analysis of the potential fracturing from injection activities. Based on the fracture model simulation, fracture propagation is not expected to occur to any fresh water zones. 20 AAC 25.252(c)(10) Actual analysis of the formation water from KU 11-17 is not available; however, the formation water analysis is included in Section D for two other Kenai Unit wells; KU 14-4 and WD-1. The formation water throughout the Kenai Unit is very consistent with these two samples. 20 AAC 25.252(c)(11) A Freshwater Exemption has been previously granted for the Kenai Unit. It is currently located at 1300 feet. The proposed injection zone is located below 5,000 feet. • 20 AAC 25.252(h) Section C contains a well schematic for wells adjacent to the proposed KU 11-7 injector. There are no adjacent wells that penetrate the injection zone within cone-quarter mile spherical radius. A cement bond log is available in section G to confirm KU 11-17 well integrity. n u A TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of Application ) For Well Conversion for Union Oil ) Company of California for Application ) of a Class II Disposal Well as Required ) by 20 AAC 25.252 ) STATE OF ALASKA ) ss. THIRD JUDICIAL DISTRICT ) AFFIDAVIT OF BRUCE W. ST. PIERRE Bruce W. St. Pierre, being first duly sworn, upon oath, disposes and states as follows: My name is Bruce W. St. Pierre. I am over 19 years old and have personal knowledge of the matters set forth herein. I am an Environmental Scientist for the well operator, Union Oil Company of California (UNOCAL). 3. Pursuant to 20 AAC 25.252(c), UNOCAL, the well operator, prepared an Application For Sundry Approvals, proposing to convert anon-producing gas well into a Class II fluids disposal well. A copy of this application is attached. 4. On October 4, 1994, pursuant to 20 AAC 25.252(c), UNOCAL sent a copy of said application registered mail to the last known address of each owner and operator within a one-quarter mile radius of KU 11-17 surface location and has notified the appropriate departments within UNOCAL. Subscribed and sworn to this 4th day of October, 1994. Br a W. St. Pier r~ e _ r,, ~. t°i STATE OF ALASKA ) ) SS. THIRD JUDICIAL DISTRICT ) The foregoing instrument was acknowledged before me this 4th da of October, 1994 by Bruce W. St. Pierre. OFFICIA! SEAL ~ State of Alaska Notary ublic, State of Alas a NC7TA32.Y :hUBLIC Roxanne M. Sinz My Commission Expires /> ~~ ",.1y Commission 6cpires August 1,1997 • . ~ , r~ , ~.~, ~,~;;r~. ~cl~~mis~i~n ~~~~i~i - • . ~ / fy 1 i ~ + ± 3 a~ L / > . ~ i - ,~' : ~ ` . 3 ~ ~ 5 ~ M ~ t~oa 4 ~ _ ~ , . « z ~ ° ~. M ~ E ~.. ~ . ~, ~ .- ~~ . ~~. 1w „ a -., 3 "" ~~ . 1 - ,~ ~- } ~` w ~~ =c~ia• ~_ -2 ~!F- ~~ ~ awl ~' ~ . ~ • k r +t 4 + + i~ - -~. ~. __ ~ f .y. ' - Vi~ i ,~ - STATE OF ALASKA ALA~OILAND GAS CONSERVATION COMMIS~I APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation shutdown _ Re-enter suspended well _ Convert to Alter casing _ Repair well _ Plugging - Time extension _ Stimulate _ Class I I Change approved program _ Pull tubing _ Variance _ Perforate _ Other ~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) m a of California UNOC ) Deveiopment_ Ex lorato KB 85' MSL feet p ry _ 3. Address Stratigraphic _ 7. Unit orProperty name PO Box 196247, Anchora e, AK 99519-624 Service, Kenai Unit 4. Location of well. at surface 768'S & 631'W of NE corner, Sec. 1 8, T~tN, 8. Well number , KU 11-17 R11W S M . . At top of productive interval 9. Permit number (Class II Disposal Well) 1-176 At effective depth 10. API number 50- 133-20349 At total depth 31'N & 1385'E of SW corner, Sec.. 8, T4N, R11W, S.M. 11. FieldlPool Kenai Gas Field 12. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface Intermediate (See original Sundry Approval) Production Liner \ l G (~j ~ ~ ~ Perforation depth: measured V L. I.d ~. ~ ~~ ° ~~ true vertical v ~.u .;.t ~ Oas ~;o;r~. Gommiss~on Tubing (size, grade, and measured depth) ~tcht)r~:.,~~< Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal ~ Detailed operations program _ BOP sketch _ Convert to a Class II disposal well. 14. Estimated date for commencing operation 15. Status of well classification as: Nov. 1, 1994 16. If proposal was verbally approved Oil _ Gas - Suspended _ Name of approver Date approved ' Service Class II Disposal 17. I hereby certify that the foregoi ng is true and correct to the best of my knowledge. Signed /,~~~~ :;f. ~ ~ Title Environmental Scientist Date 10/4/94 Conditions of approval: Notify Commission so representative may witness Approval No. Plug integrity ~ BOP Test - Location clearance _ Mechanical Integrity Test _ Subsequent form required 10- Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE • ~a 1 0 I ~ N I `~ 1 ~, a 0 in 0 N /J.~NII NWlorlaf YNII ~ ~j Q If-1 ~ ° ~ ~11J ~ lL S QDP~ N/~ ST ~~~m~o~mo a~a~ ~o~o~ X• 2r3,33r,a3 r.Y,3ss,rr,~1Y wpll r Q p•Y)3,331.6 T•Y,]SS,iS1.t TN I~hElpp El. fii 4r Top2 PW EI.fir32 c n Y• Y,338,Y30 T•s,33fiPO0 r• t,sss,wo ~~~'~~ ., ... . ~''.,. ~ Ypw~„a, I I Y LOCAT -- - -~ %; - . . 0 41-18 ~ ; - u ) ., I E ,~•wl I VICINITY MAP SCALE 1"= Imile LEGEND AND NOTES F Found brcu cap monument e Sff I/2" s 24" steel rebor. o- power pole with anrAfod aervlcf. Eaisling well chriaMms Tree Inside small steel building. 9 Found2"PVCplpe or as need (Abnifafng Wells), Referopce delum Is Mean Sec Leval = 0.0 for elevalwns shown. Elevofiona hove been reviatd ro coEdorm wifA the orfglnal well calla Fw KU I I-17 and Mean Sea Level Datum of 0.00 (7-23-85). 411 bearings aro grid esceplnofed otherwise. Bosis of CoadmaNs if USC.BGS. 7ri Slotion AUDRY In A.S.R 20M 4. Awroge convergence pf poln6 shown - I° 04.5B° AUDRY Lot fi0° 30~ 50.559"N Lang l51.16~ 87.445°W X= 269,866.75 Y c 2,382,045.42 ENvefions of fM fop d pipe fa malilainp wel4 wfn taken wffh Bova of-or opfn. Added K.U. 33-7 4 - I - B8 Addle Sodbn Lk~o 2 - 4 - 66 Addb X 6 Y CoadkEOhf to all locallom I I- I Addb hbnlfa NMI B and oMd 7- 23 Rwif4d Elfr. on South Monllor Wdl 5 - IB-88 Added Monitorln Wdle 2 - 19-86 Updatfd 10 - 29- 63 REVISIONS DATE U~I~~AL KENAI GAS FIELD PAD 41-18 AS-QUIL`~ SURVEY UNOCAL P.0 Sox 180247 Anclaragf, Alalm 118 5 0 2-0 2 47 9urwlled brE MCLANE and ASSOCIATES, INC. Soldoha, AK. 89869 DATEOFBURVEY 8CALE SHEET 12-18-81b1-27-82 I~ ^ 603 I of I U + ~.. ~ to • KDU ~. ts. e • KU 11-8 • . s 38 X tS3 • o ~ * + , 9~ P 70 3 7 yc KBU 13-8 t99 . o • 6H~ 8no KU 43-7 ~ • • 18p 0 f • 36 x ~ ~~S 0 s 130 + • / f I7~ 0 ~ KUH 1 b ,~ gN~ N . 4 ~y~7L1 3$ X pt o ~ KU Li-17 e g, H, L Y ~ S3'~O 16N o t~, 1 v O + 34 • 162 0 j3 ~o + ~ 33 X Z~ + y J 25 o t~'~o ~o + t Sti d." 3~9p + ci to ~~ ' So 32 ~,0 p ~HU 44-18 + '~' `~ • AtosiES District KENAI GAS FtELQ icoo 31 >K ... ... N .... • y FEET Y a WELL. LOCAt'~L~3I~` z ,,,:; _- o g~ , 1. _J-` ~o DE3 DR, AK. ~~ PRoD ~~/TE/4-6 I~ I ~ui~ `~' ~ - ~ \ ~_ • 5~ i i i i i i ~~ • rs' -w= ~• - I 9' ,~ ,~,~ ~~ i ;. i €~,z .. ~ ;~~: I ,~ I ~: a I ' :_~ I s I I I i I I I I I __--r ,~, _,~ 5 _- I . - _ _- ~ -~~ ~- ~~IP.___-sirF4/-~ I ~ ~ I I I I ~ I I la I to I A-028142 I q I 2580ac. I I • CIRI SUBSURFACE SALAMANTOF VILLAGE SURFACE I FPlTISG LE~,SE I I I I I _~ sirE4/-/8 I )D EGIUIP I _ j .~ I ADL-2233G I I 1 864, 72ac. ' CIRI Surface a Subsurface I Entire Leas•+ I a.. , ~..: yf I ~~~~ I " = I,ooo' i' ~~la 0~1~& Gas Cons. ~~,. ~ I~.,.u, ~I s~4~E r.... • ~I i ra~M'~"; ~I ~I r~ ---~-.~.._:i_.~I STATE ~ _ Q _%-~ BORO 8EL. APIN. 66708 , _'.!'.t._ ~;,Wn SITE 41 I Auq 77 1 ~ ADL-324b98 ~ Ju~Y' 7' PROD. EQUIP. 840ec. ~ • Nov 78 ~;~ _--_ PROD. • P `~?35 335 1Q4 Certified Mail Receipt No Insurance Coverage Provided ~~ Do not use for International Mail '~":~Pn"~ES fSee Reversal Sent Street & No. to #10 P.O., State S ZIP Code 6~~ Posta Certified Fee Special Delivery Fee Restricted Delivery Fee Return Receipt Showing to Whom & Date Delivered Return Receipt Showing to Whom, Date, & Address of Delivery TOTAL Postage & Fees Postmark or Date - .•. P 9015 335 104 /~~ O O) Of N c 7 O O M O (n a rvt( • Certified Mail Receipt No Insurance Coverage Provided ~~ Do not use for International Mail uwigo sgres (Spp Qgrrp rc nl Sent ~~2d Street & No. ~vl ~ ,5~- ~: ~o PO., State 8 ZIP Code ~/ ~/ ~ ~/j~ / ~~~ Postage Certified Fee Special Delivery Fee Restricted Delivery Fee Return Receipt Showing to Whom & Date Delivered Return Receipt Showing Io Whorn, Date, & Address of Delivery TOTAL Postage & Fees Postmark or Date .. • .•- ... ~ . , P ~CiS ~~ ~ 1.57 ~~ ~ ,w ~, >~_ ~ `~' ~~ 0 "~9 1 -.Y.... '~ _, ~ ~~ :~ t-~. -~~ Certified Mail Receipt No Insurance Coverage Provided Do not use for International Mail C ,~ ~ ~` A~ c~ ~ T J+ !'" 4 Gr. (IF L~ t•"7 1 .7 ;: ~1 ~.+ q~.w~q/ ~..:+~" P `I05 33.5 I.~9 Certified Mail Receipt l No Insurance Coverage Provided ~~ Do not use for International Mail °~~;~E (See Reverse) C c C t C C C C Fc • p `]U S 335 1,05 Certified Mail Receipt No Insurance Coverage Provided Do not use for International Mail ICPP RPVersel SenttoX~ c ~ R ~ m~ ~ ~,>~ Street 8 No. S C PO., State 8 ZIP Code 14K ~45b Postage Certified Fee Special Delivery Fee Restricted Delivery Fee Return Receipt Showing ~ to Whom & Date Delivered i Return Receipt Showing to Whom, Date, & Address of Delivery i ~ TOTAL Postage ~ 8 Fees ~ Postmark or Oate 1 ry L ... - .. - ... ® ~ ^ P 90.5 335 1~0 `=_ ® , ®~~ J r I~~ C ~ ~ RESERVOIR INFORMATION KU 11-17 WELL, KENAI GAS FIELD, ALASKA Criteria for choosing a disposal well included• • using a well bore which has no future potential for production, • determining that the well has sufficient disposal capacity into one or both of the already permitted and approved Sterling sands, • checking strata maps to insure substantial vertical confinement, • looking at Cement Bond Logs to insure mechanical integrity, and • adequate tubing size. The well that best fits these criteria is KU 11-17, located on KGF Pad 41-18. This Kenai gas well has no future potential as a producer. The short string died in July of 1993, and the long string in February '93. The short string can be selectively injected into either or both of the B3 and B4 sands. Possible short string injection zones from well KU 11-17 include 32 feet of the B3 sand (4,465'- 4,483' MD), 150' of the B4 sand (4,522'- 4,586' & 4,614'- 4,700'). Long string injection potential includes 128' of the C1 sand (5,102'- 5,155') & 5,172'- 5,247'). Attachment #2 indicates perforation intervals within each possible injection interval. The perforation intervals are shorter than the injection zone, the values listed above are the top and bottom depth of each respective Sterling sand zone. • The exemption limit is 1,300' for the Kenai Gas Field, so the proposed interval of injection is well below the specified limits. There are a numerous laterally continuous shale layers above the sands and 173' (4,465'- 4,292') of solid cement bond in the casing annulus directly above the zone. The dual 3 1 /2" strings are of adequate size, and the site is not easily accessible to the public. Fluids planned for injection include produced water from the Kenai Gas Field and Cannery Loop Unit Gas Field. In addition, non-hazardous waste fluids generated by normal drilling and production operations would qualify to be injected down the Class II disposal well. This includes, but is not limited to, slurries of drilling mud, NORM scale, and other exempt drilling and production wastes. Maximum disposal is not expected to exceed 3000 barrels of fluid per day. Current field reports indicate an average injection volume ranging between 50 and 100 barrels per day. The surface location is within the Kenai Gas Field Unit, and the working interest is divided among Unocal, Marathon, and Chevron. Land ownership includes Cook Inlet Region, Inc. (CIRI) and Salamatof, Inc. The Bureau of Land Management (BLM) manages the federal lease. All applicable agencies, working interest owners, and land owners will receive a copy of this application. Attachment #1 includes data from the MIT done in June of 1994. Attachment #2 consists of wellbore schematics of the disposal well. Attachment #3 shows the surface location • and the approximate bottom hole location in relation to other wells in the vicinity. There are no wells completed in the proposed injection zones within a 1/4 mile radius of 11-17. • MIT Procedure: Hold orientation meeting Pressure casing to 1,000 psi Hold for 24 hours Record surface casing pressure Results: 6-10-94 1,000 psi 6-11-94 988 psi Casing lost 12 psi in 24 hours. ~~~~~. r r . ~~c~ ~ti ~ ~a~ C0;"I5. C~rt-~mi~si~R ,_ ~nch~~r~ Attachment #1 Mechanical {nteyritYTest Operator Field Pad Well Type Date Unocal Kenai Unit 41-18 11-17 Idle 6-10-94 • x:luserslepargya\word~wordV~gf~n~d well.doc sped: a oa o0 ~omplefed: 3~~~82 fast Work QVer: 00~00~00 I~~ ~~~_~,, i 1-11~ ~~;eriai Gas Field API No.: ~0-133-20349-DO ATir~CHMENT ~ 2 0 - 116' 20" OD 94.QO~~ft CSG DRIVEN ~ Q - 1994' 13.315" OD 61.OO~~ff J-56 SURE CSG 0 - 5371' 9 5~8" OD 47,00#~ft N-80 PROD CSG 4641 - 4661' SQUEEZE PERES Sgt'd lower B-4 6103 - 5105' SQUEEZE PERES Isolation Sqz. 6160 - 5162' SQUEEZE PERES Isolation Sqz. ~~l ~ ~ lop ~~ F~~.~~: F.. r'~~ R~gle C~ Perfs 0.0 Degs. Har7ger: L 19 - 5048' 3.5" OD 2.99" ID 9.20#~ft N-80 TBG LONG STRING 19 - 4520' 3.500" UD 9,20~~ft N-80 TBC SHORT STRING 446$ - 4483' PERES B-3 4528 - 4581' PERES B-4 5106 - 5152' PERES C-1 RECEIVED • OCT - 7 1994 ~a~ka Dii & Gas Cons. Commission ~_,,~~ ~inchora~e Gos Well Pools Sands: ~. i & 6 PBTD: 5311' TD: 5311' Spud: a oa oa t;omplefed: 3~~~82 ~ Lasf dark aver: aO~aO~aO C~ KGF 11-17 Kenai Gas f field API Na.: ~a-133-2049-oa ATTAGHMENI ~ 2 Up of Prr~~d. F~, r'~~~ Angle ~ Perf s a.a Qegs. Har7ger: 19 - 5048' 3.5" OD 2,99" ID 9.~O~~1t N-80 TBG LONC SIRING 4343 - 4347' SLEEVE Otis XA 4347 - 4357' RE1RV. PACKER Baker A-5 Dual Pkr. 4641- 4661' SQUEEZE PERES Sgz'd lower B-4 • 4456 - 4605' BLASST JOINT Baker 4468 - 4483' PERES B-3 4505 - 4615 RETRV. PACKER Baker AL-5 Dual Pkr. 4528 - 4581' PERES B-4 46UJ - 4611' SLEEVE Otis ~ 4620 - 4621' lOCA10R JOINT 4621- 4626' PACKER Baker D Pkr. W~Seal Asst'. 5015 - 5016' LANDING NIPPLE Otis X 4999 - 4999' LOCATOR JOINT 4999 - 5004' PACKER Baker D Pkr. W~Seal Asst'. 5046 - 5047' MULESHOE Baker Bull Nose Entry Guide 5103 - 5105' SQUEEZE PERES Isolation Sqt. 5160 - 5162' SQUEEZE PERES Isolation Sqt. 5106 - 5152' PERES C-1 RECEIVED 0 - 5371' 9 5 f 8" OD 47.OO~~ff N-80 PROD CSG 5371- 5371' SHOE r~ L OCT - 7 1994 ~,4ask~ Oii & Gas Cons. Commission - -~--,~. ~-nchorr.e Gas Well Pools~Sands: #~.1 ~ #6 PBTD: 5311' 1D. 5371' Spud: 0 00 00 Completed: 3~5~81 ~ Fasf ~1ark Oyer: Q0~00~00 KGF 11-17 Kauai Gas Field API Na.: ~Q-1~3-20349-DO ATTACHMENT # 2 ~~ ~ - ~ Ft. r~o lop of Frod. Angle C~ Perfs: O.Q Degs. Hanger: 19 - 4520' 3.500" OD 9.20#~it N-80 TBG SHORT STRING 433i - 4341' SLEEVE Olin i~ 4351- 4351' JOINT left Hand Safely Sub 4351- 4361' RE1RV. PACKER Baku A-5 Dual Pkr. 4362 - 4362' TRAVEL JOINT Baker Telescoping Swivel Sub 4468 - 4483' PERFS B-3 4430 - 4434' SLEEVE Otis ~ {Open 6 f 20 f 93} 4528 - 4581' PERFS B-4 • 4641- 4661' SQUEEZE PERFS Sg1'd lower B-4 5103 - 5105' SQUEEZE PERFS Isolation Sqt. 5160 - 5162' SQUEEZE PERFS Isolation Sqt. 0 - 5371' 9 5~8" OD 47.00#~ft N-80 PROD CSG 5371- 5371' SHOE 4507 - 4508' JOINT Left Hand Safely Sub 4508 - 4518' REiRV. PACKER Baker AI-5 Dual Pkr, 4519 - 4520' LANDING NIPPLE Otis XN 5106 - 5152' PEKES C-1 RECEIVED OCT - 7 1994 Alaska Oil & Gas Cons. commission Anchor. ;e Gas >~dell Paols~Sands: #5.1 & ~6 PUTD: 5371' TD. 5371' 701 • • . CHEMICAL & GE~IL()CICAL LABpRA7'ClR1ES 4~' AGASICA- INC. P.O. BOX 4.1276 TELEPHONE ANCHORAGE INDUSTRIAL LENTEN 907 562.2343 5833 Street wo~•*o~~^^ Anchorage, Alaska 99509 ( ) WATER ANALYSIS R-SPORT OPERATOR ~pt^~ WELL NO. _ tn1D #1 /~~iLAX ~ Cl..v FIELD Kenai Gas Field COUNTY __. • STAtE Ala~- REMARKS & CONCLUSION DATE 1/3U/9a. _ LAB NO. 91.Q4QL-1. LOCATION Cantlts~y_ ~-- - FORMATION _. - - INTERVAL SAMPLE FROM WD ~1..E~-1ter~ - S: ~ium ~ mg~1-- 0.94-. _ Stron~i« _--m9/1 -~ . 51 ---won---. - ~3~- .~4 -- l - Cations m !~ fI magli Anions lt1~11 21 .......... _ Sodium . 614 -- _ 26 .77 9ultete .... , 640 . Pvtasalum ..... • • . • • • - ~- - - ~- • 46 ........ Chloride ... - • . .......... Calcium __ 51 _ _ 2.54 , ' . , Carbonats .. _ . ~4 _ . 23 1 • $~_ • . • . - . • . Bicarbonate Megnestum ...... ... _ ._ _. . • , , . • . - . - Hydroxide . Iron .... ........ .. _ _.. • ...... -32.6f~ Total Catlona • Total dlesolved eollds, mgl1........ • • - 18~? NaC1 equivaiant, rttgll ....... - • • ... _ .165Q- Obatarved pH ....... ...... ........ __7.3~ ma ~t 0.44- ls..o~ ~,4.1Z- _ TotA~ Anlona .. • • • • • • _ ~~-- Specific reslstenct: ~~ de ° F•: -.~ • 2 - ohm•metera Observed ....••••• Calculated . • • • • • • • • ~~.9 -ohm•ntetera WATER ANALYSIS PATTERN Scale MEO per Unit Na Ca Mg Fe • ZOd 9t0 Ct 10 Na HGO' 1 Ca SOa 1 M9 CO' 1 Fe (rya tatya In ^bora 9rapht MolaOaa Na, K. «,d U) NOTE: twyn - Mllllyrama par ItNr Magr1 ~ MNHpnm aqulraNnl o^r Ntar 9odlum Chlorfda aqul.atant-by O~nlap i Maw-homa aaleuUtlon Iron componanta C1 HCO' SO• CO' OZ~St ZO-b0-i66 Samvle above described -_ _ _J ~ ~ CHEMICAL 8c GEOLOGICAL l.AI30RATORIES OF ~tLASK.4, INC. '` P.O. BOX 4.1276 TELEPHONE ANCHORAGE INDUSTRIAL CENTER 5633 8 Street ~,,.°,~w,... Anchorage, Alaska 99509 (9071 562'2343 WATER ANALYSIS REPORT _ DATE~.30-9L- LAB NO. 91.D-4.4~-=-~ OPERATOR Fn`~'A't' £ At fl rE _ LOCATION .tannery Img- WELL NO. -~-4--~ ~-~ _ FORMATION - - FiELD__ .~~n~-~- F~~-- INTERVAL- - COUNTY _ SAMPLE FROM l d-d . - SLATE -. ~l~S~-- REMARKS & CONCLUSIONS: x4xr91IiT1 Str~acatium --T Cations m9/1 megl~ Sodtum ............. 6.00 26.09 - Potaseium ... ....... 58 -- 1.48 Catclum ............. 50 . ._ _ 2.50 . Magnesium .......... 23 __._ .1.89 Iron ....... ...... - - _mg/1„ 0.88. - - ~ - --~~1 -4..49. ~~-- - b _ 76 _ - r Aniona .~- mg11 mepll Suitata .... ...... 1~.~- 17.4g 620 - Chloride ....... ..... - Carbonate ...... . - . • ~ Bicarbonate ... ..... g69 5 Hydroxide .... . 31.96 Total Anions .......... 37..9b-. Total Gatione .. • • . • • - • - _ - - --- total dissolved solids, malt ....... 185b SpecHlc resistance ~u~ 68° F-= ... _ . 1610 Observed ...... • • - - -3.2 - ohm•me era NeC1 equlvatent, mg11 .......... • • • - 7:42 - _ q • Q.._ ohmmeters Calculated .. • . • . . Observed pH .. ................ ... - Na Ca Mg Fe CO' 1 t=a (N~ vdw In •ber~ Or~Dfi~ In°fuMf Nt. K, end L1! NOTE MQ71 - MlNlpnm~ per Ml~r Magl1 : MIIlignm .quIY~NM ~r Ilia $prllum Chlorld~ pul.~Nnt~bl• G~~ k H~wthurr caieu1~11V° from comp°°Mt. WATER ANALYSIS PATTERN Scale MEQ per Unlt Ct 10 Na HCO' 1 Ca SO• 1 MA Ci NCO' SO' CO' OOd 9t0 iZ~Si ZO-bO-[66 Sample above described 4 • NALCO CHEMICAL COMPANY • BDX 3889 = KENAI. ALASKA 89619 Aq~A 9~7-283-3589 GAS ANALYSIS REPORT Company i Com an Date 1-22-86 Well No. 11-17-t Location Kenai gasfield Field Kenai gasfield Date Collected 1-12-86 City Date Ran 1-15-86 State Alaska Sampling Point 11-17-L Sampled by Line Pressure prig: Sample Prssure psig: Temperature °F: Container #, Remarks Hexane (C6) ......................................... 0.0000 Oxygen (02 + Ar) ..................................... _0.0058 Nitrogen (N2) ........................................ 0.5315 Methane (Cl)• ........................................ 99.3127 Carbon Dioxide (C02) ................................. 0.0446 • Ethane (C2) ......................................... 0.1054 Propane (C3) ......................................... Iso-butane (IC4) .................................... N-butane (NC4) ...................................... Iso-pentane (IC5) ....... ............................ N-pentane (NC5) ..................................... Total ............. 100.00 Gross btu cu. ft. @ 60°F & 14.7 psia (dry basis)...... 1007.21 Specific gravity (calculated from analysis)..... ... .5585 . Specific gravity (measured) .......................... Remarks Analyst _ + t • NALCO CHEMICAL COMPANY • B:JY. 3889 ~ KENAL ALASKA X8699 ~ AREG. 9~7-263-3589 GAS ANALYSIS REPORT Company Union Oil Company Date 1-22-86 Well No. 11-17-S Location ena~ gas ~e Field Kenai gasfield Date Coll ected - - City Kenai Date Ran - - State Alaska Sampling Point - - Sampled by Line Press ure psig: Sample Prssure psig: Temperature °F: Container r_ Remarks Hexane (C6) ......................................... 0.0000 Oxygen (02 + Ar} ..................................... 0.0080 Nitrogen (N2) ........................................ 0.7656 Methane (C1) ......................................... 99.0594 Carbon Dioxide (C02) ................................. 0.0612 • Ethane (C2) ......................................... 0.1058 _ Propane (C3) ......................................... Iso-butane (IC4) .................................... N-butane (NC4) ....................................... Iso-pentane (IC5) .................................... N-pentane (NC5) ...................................... Total ............. 100.00 Gross btu cu. ft. @ 60°F & 14.7 psia (dry basis)...... 1004.65 Specific gravity (calculated from analysis.)........... Specific gravity (measured) .......................... Remarks Analy t • • .] DISPOSAL FLUID ANALYSIS Type and Source: The injection fluid for disposal is predominately produced water. The injection stream may include drilling mud slurry, reserve pit water, equipment washwater, tank bottom materials, drilling/completion fluids, workover fluids, diesel gel, glycol, NORM scale, and other Class II applicable waste. General Physical Characteristics of Injection Fluids: 1.) Produced water: The produced water at the Kenai Gas Field averages approximately 1,800 mg/I total dissolved solids with typical properties as shown on the water analytical reports from WD-1 and KU 14-4 (Section D). 2.) Drilling Mud: Normally, a lightly treated Lignosulfonate with 3% KCI was used within KGF which has the following general properties. This mud is similar to Type 1 mud approved by EPA for NPDES General permits. Table 1. MATERIAL Percent by Weight Pounds per Barrel Pounds per Gallon Fresh water 80-90 350 8.33 Benonite 3-4 12-18 0.3-0.4 Barite 12-24 45-100 1.07-2.38 Potassium Chloride (KCI) 0-5.2 11-22 0.26-0.52 Lignosulfonate 0-2 0-8 0-0.2 Polyanionic Cellulose 0-0.7 0-3 0-0.07 Potassium Hydroxide 0-0.1 0-0.5 0-0.01 Caustic Soda 0-1.1 0-5 0-0.11 Acrylic Polymer (Bentonite Extender) 0-0.5 0-2.0 0-0.05 Sodium Nitrate 0-0.02 0-0.1 0-0.002 Lime 0-5 0-20.0 0-0.5 Soda Ash/Sodium Bicarbonate 0-0.5 0-5.0 0-0.11 Lost Circulation Material 0-2.5 0-10.5 0-0.25 TOTAL 100.0 420-504 10.0-12.0 • (Continued) n • • 3.) Completion Fluids: Normally 3°~ KCI and saturated NaCI brine with the following properties: Table 2. MATERIAL Percent by Weight Pounds per Barrel Pounds per Gallon Fresh Water 83.3 350 8.33 Potassium Chloride (KCI) 3.0 12 0.30 Sodium Chloride (NaCI) 13.3 57 1.35 XC Polymer 0.4 1 0.02 TOTAL 100.0 420 10.0 The drilling/completion fluids and workover fluids proposed for injection are not defined as hazardous by the Resource Conservation and Recovery Act (RCRA). The drilling mud described in Table 1 is essentially similar to Generic Mud No. 1 as identified by EPA and approved for offshore discharge under the auspices of a National Pollution Discharge Elimination System (NPDES) permit. Compatibilitywith formation and confining zones- The vast majority of injected fluid is • produced waters and formation materials (cuttings, NORM etc.) which are compatible with the injection formation. • ~ ~ GEOLOGIC FORMATION SIIMMARY RII i1-17 WELL, RENAI GAS FIELD, ALASKA A subsurface evaluation was conducted to determine the stratigraphic relationship of the freshwater aquifers and the proposed disposal well sands in the Kenai Gas Field. Results and Conclusions: Plate 1 is a north-south stratigraphic cross-section showing the lateral continuity of the impermeable shale intervals. These shale intervals act as upper and lower confining impermeable units in the sand-rich Sterling Formation. The shales vary in thickness from three to 40 feet. The data available is conclusive that the shales are widespread and prevent vertical fluid communication between sandstones. Plate 1 also shows the stratigraphic relationship of the freshwater aquifers and impermeable claystone intervals in the Pleistocene strata overlying the Sterling Formation. These freshwater aquifers are generally fluvial channel sands bounded by lacustrine claystones. A major unconformity lies at the base of the Pleistocene strata (top Pliocene Sterling Formation). This unconformity also acts as a barrier between the freshwater zone and the more highly saline Sterling Formation sands. The sediments below the base of the glacial deposits are in the upper and middle part of the Sterling Formation. These sediments are sands, siltstones, shales and occasional thin- bedded coals. The sands are highly unconsolidated and are generally uncemented. Intervals shaded brown on the type log indicate impermeable shale zones. Waste water is currently being injected in the Sterling Formation sands that are colored dark green. ~ ~ ~~ ~ ["~ ~" ~...,~ =tl~ ~, . ; .t ~ .. ;.... .:'~:~ l.,.~ { i Lcti`d' V4kf t~ VsI 1TIIJJIO.4• PREVIOUS DISPOSAL INTERVALS a PROPOSED DISPOSAL INTERVALS p~~„s~~ Vu~~ ,:.,,~ F~ F~9dp,,-. llNOCALQ Unocal North American Oil & Gas Division ALASKA BUSINESS UNIT KENAI GAS FIELD KU 11-17 PROPOSED DISPOSAL WELL CORRELATION SECTION A-A' Interpretation by: ERIK P. GRAVEN Date: 10/94 Scale: Drafted by: File Number: F - • ~ unoesl op i cas O , Unocal Coraoraton P.O. BOx 190247 Anchorage. AIat,Ka 99519-0247 Telephone (907) 276-7600 • ~r i~f ~~ Alaska Distract April 8, 1987 T0: S. A. Lanbert FROM: ~1. R. Starzer ~,~J RE: KU 14-4 STEP RATE TEST ANO TEMPERATURE SURVEY .MARCH 30, 1987 • A step rate test and injection temperature surveys have been run on KU 14-4 in preparation for cisposal service. KU 14-4 is currently open in the pool 4, B-1 sand with 56' of perforated interval from 4194' to 4250' (htDl. Prior to infection, fill was ta95ed at 4235' leaving 41' of the perforated interval open. The following stauilized injection rates ano pressures were recoraee. Rate Bottorlhole Injection Pressure 5 6Ptd ° Pre-Test Temperature Survey 5 1891 PSiG 6 1962 7 2019 8 2260 2466 2 ° Post-Test Temperature-survey ° Static Temperature Survey Three temperature surveys were performea. Tne survey designated Run !~1 was taken prior to the infectivity test at a rate of 5 BPM and.. 500 psig suri3c~: injecticn~ pressuro. ,, ~,:~ r:=2 io ~~c ;.:at-•~zst ::urvo`~' taken;; rn^7~t ~tPC -~f~or .-tr,o ~,; X1^!'.:T SUSt ' ^ ~ ~ : ~., :a,. `, .°: late. 'J¢ i ur~i~l, Rif.^. ~E~ is the post-test static survey. Anomalies in Run 0.1 near the. packer and locator are due to the 'L' sleeve at 4111' being open allowing cool water tin the backside. The sliding sleeve vras closed after the static. ,. ••- •1 KU i4-4 StEp Rate Test and • Tenperature Survey - March 30, 1987 April 8, 187 Page Two survey In preparation for the mechanical integrity test. All surveys aemonstrate injection occurring within the B-1 sang of Pool 4 and no cnannei~ng Gehino casin=~. There is no indication of injection above the confining shale intervals into possiole sources of fresh water. The B-1 sans within the Kenai Gas Fielc is under-pressured sue to aepletion from the gas pool. A fluid level taKEn in i4-4 prior to the step rate test indicates a localized B-1 formation pressure of approximately 1'120 psis. Losses across the perforations and sandface approach ~5U psi at an injection gate cf ~ BPt•1, increasing linearly to 1250 psi at y BPfi. Pdo inoication or formation oreaE;dewn occurreG up to iyUO psig injection pressure. Tree fracture gradient for tre B-1 sand it 14-4 is in excess of .89 psi/f t. Applying a multiple rate transient analysis to the test yields a permeability to the injection fluids of approximately 75 i~tD ~~ith a stimulates shin, conparaoie to transients anaiyzec e1se~,r~ere witt'~in the fiela. Attaches is the step rate test hall plot and tarYerature survey log. • MRS:v!f:041~r cc: C. Lockwood Ft. ~. ~cO~ert5 8. C. Sr.~ith - Fi elc Weli rile KU 14-4 Drell rile • • tisoo cr~ w : soo . u: ~ ~ ~o~ v~ G'' li. ~ a :x`200 :I z O ~_ ~ o00 w ? feoo u.' I ~soo O ~ `400 .... ~ 'l200 4. • I<ENAI GAS FIELD WELL KU 14-4 STEP RATE TEST March 30th. 1987 ..... ...., ..v n.u wnTFR ~N.IECTION RATE (E3PM) ~.o ~~ • i ~~ i ~~ Bi 9ERVIt3EB Quinn AikEns Unocal 909 West 9th Avenue Anchorage, Ak 99519-0247 Dear Mr. Aikens, Enclosed is the fracture simulation you requested for the Kenai Gas Pield well 11-17. Since critical data for fracture modeling was not available, estimates were made to the predominate parameters of young modules, insitu stress profile, and total fluid loss coefficient. The model is setup to simulated a three layer reservoir. This assumes that the gross horizon above the C-1 zone has uniform characteristics. The Erse model run is based an a stress prof le of 0.78 psi/ft from 3000"TVD to the bottom of the C-1 formation, 'The only parameter difference between the injection horizon and the upper horizon is a reservoir pit;ssw~e difference of 800 psi, A slightly higher insitu stress was given to the lower section below the C-1. The fluid used was a linear iS gpt gel carrying 3 ppg 80 mesh drill cuttings. The young modules is assume to be 4.0 E+6 in all three layers, With these parameters, the model predicted upward growth with a declining net pressure pumping at 10 bpm for 100,000 gallons, • The model run depicts the geometry created for drill cutting disposal using the above parameters. The actual fracture geometry will vary depending rock properties, fluids properties, and pump rate. Sincerely, Jim S Region Engineer CC: Ed Post • z'd NOIldd0~dx3 dH WdLb:80 b6. SZ 1~0 • t OJ4A/1994 16:28:11 • MFRAC-II A THREE-DIMENSIONAL HYDRAULIC FRACTURING SIMULATOR MPRAGII b a trddemaNC belengtng to MEYER A ASSOCL4TES,be. COPYRIGHT (C)19B$-1884 MEYER 5C ASSOCIATES,IMGr WI 19ghte rAeArved 2886 Old Freeport Rd., Natrona Heights, Pa. (U.S.A.)13085 COMPANY: Unocal YIELL: 11-1T LOCATION: Kenai [tae Fkld DATE: October 24,1394 COMMENTS: Iraection yell into fo demoetrete cutlYtg disposal 6racture geomelty. RUN OPTIONS Simuletlon Method Design Mode Net ProeeM Valw ON Fracture Oeomelry Three~Diinensienal Heal 7lrunahr Of Fa M116/ Ten1p. =102.0 ('F) LsiyMlt OptNlt Calwbte Length PtuW Less Medol Constant ProppaM Option Input $ohedub Pipe FMbNon Model Nerve Fracture InMINbn Yderval PertorWed Y:tervul Arop Conc. Input as Liquid Pressure Deellne Olf Proppant Setllla8 Optbn Uaer SpeoNfed Reaetlve Fuide Off PFadure Flrb/bn Model Off Wall Rougtute~ OH Fraoturo'rAs' Effects ON • Fraalere Fxtla crwattt . ao only Inoiuded ProppaM Ramp oN Multlpa zones off Ne, of Free Soln. iterations a0 Prop. Soln. call Frequency 2 PAY ZONE DATA lend Depth f~rart Depth To Perm. (-) (K) (H) (md) • C-1 4696 4375 200 PERFORATION nATA Tans Duptl, From Depth to No. of Nerfs Pert Dtarnefer (-) tnt (it) l•) pM G1 4596 4841 800 0.42 Near Well/Perfora#ion Drop Table Tfma Pressure Drop (min) (pat) 1 S 10 60 100 Zorro (-f tta~ toa~nee~ a•d -- - _ - 0 0 0 0 0 ROCK PROPERTIES Young's Poisson's Frecture Stress Depth Stress Modulus Ratio Youghness 6redlent (K) fan (Psi) (-) (psFinl'W (~ -~- NOIld~i0~dX3 dH WdLb:80 b6. S2 1~0 • Young's Poisson's praCWre titres Tans Deptlt Stress Modulus Rath Toughness Gradknt • (-) (h1 (Pelt lPa4 (-) (PsFln1~I (-) t}1 Tep 4$Oq $S$a ge~QO 0.2 1000 ON G7 4844 8622 4eW6 0.2 1000 ON a1 lower a7uo 4000 4ea09 os f o0D ON FLUID LOSS DATA Total Fluid Logs Depot Cosffkfent 8pur1 Lose (te) (ft/minls) (gdVlt~ 4594 o.99z 0 4644 0.002 0 d700 0.002 0 TREATMENT SCHEDULS Prop Prop Pump titage pumpM9 Fluid Prsp Prop Damage BetiSng Rate Vohime Tyne Type Type Cone. Factor Rate (bpm) (US. gat) (min) (-) (-f (D+rn/9~) (-) (~+tti) 10 1e+05 249.87 e~ 0 1 os o.f Fluid Type M006 - Sllolc Water w/ 16 Ibs polymerA00D gale Proppent Type OOOO - 80 Mesh brill Cultlngs SUMMARY TREATMENT SCHEDULE Stage Slurry Slurry Liquid FIuM Prop Coro. Conc. Prop. Stage No. pate Volume Volume Typs Type From To Mass c-~ (bPml (us. San (u.a 9on (•- (-) (ten o~e~n (~+a • 1 10 1.0458ea0S 1e+OS MOOS 0 1 1 1e~ Total Slurry Volume 1.04S9et05 (U.S, gal) Total Liquid VoMane 1e+OS (U.S. gel) Tetal tang Mass 1e+06 (lam) Fluhl Type MODS • SUelt Water t+d 1S Iba polymerAD00 gels Proppiatt Type 0000 - 80 Mesh brill Cultktga PROPPANT DATA No. Preppant layers far Bridging a MM ConJAreA for FCO 0.1 (Ibmlft~ Cbaure Pressure on Proppant 5000 (Pei FRACTURE PROPAGATION SOLUTION Avg Avg Width tret Fractur e Mss. wroth ut over Upper Lowtx Fluid Tyne Volume Pressure BHP Length Width Nreltbore Length He1gM Height tffklenoy (min) (u.5. gaq (psi) lpe4 IM (In) (IM (k) (n) (M l-) 0,067741 28.451 204.78 9788,3 12 0.059028 OA402O2 OA84108 24 ~ 0.87816 OA9924 41.681 804.9 9789.6 14.418 0.054942 0.0412 OA95982 25.983 x.754 0.68627 0,14702 61.718 208.54 8788.1 17.894 0.057607 OAd535d OA98484 28515 27.95 O.ti9937 0.22111 92.064 201.14 3985.Y 20994 0.080874 OA47878 0.040891 81.784 80.566 0.58051 0.29783 125A1 199.16 8783.7 24 0.062684 oAW4a1 oAa1968 84.595 92b12 O.S9022 0.43929 189.12 196.14 9780.7 Y9.978 0.0991a7 0.061874 OA440/2 88.141 85.642 0.48905 0.66644 266.8 193.14 5777.7 3x.19 0.069266 0.054255 OA48078 x4.858 36.672 0.44686 1A509 141.86 190.43 8776 40.565 0.072209 O.QS962 OAd8079 51.184 42.177 0.4W17 1.6158 678x11 187.96 97725 47.859 0.07514 OAS9086 OA60107 58.861 aS~7s 0.866 2.4912 1048.7 185.6 9770.2 56.868 0.079888 OA61S68 OA52188 67,658 16.684 0.124 • 8.8ti27 1816.1 188.06 8767.8 65.877 0.090654 0,064412 OA54479 78.288 B1.7i'8 0.29295 5.9891 2512.8 178,78 8764,9 76.543 8083919 0.088112 OA57914 90.405 P4.886 0.24888 9x96 8906.1 17x.49 ar60 sa.86 8097208 9A7298S OAeo567 104.41 57.878 0.2179 14428 6060.1 170,97 3754,8 1ot.ae 0.090636 OA77812 0.064319 120.57 69.906 0.19079 2Q.944 9884.9 184A 9748 11669 0.088715 oaa29o7 OA6853 180.19 61A9s O.ltrati~ el A7 18049 189.29 8743.8 127.86 0.095587 0.087285 OA7tiSS 186.17 88.179 815047 1 t 17 ~aDmtee4 - 2 , E ' d NOI lti2iO~dX3 dli WHBb : 80 b6 ~ SZ 1~0 • Tlma (min) VOItIme (U.S.9ei) Net Prossuni IPa~I F'radure ®NP (paq Length (h) Max. Wultl- (in) Avg Width at welWOre (in) Avg Wfdlh over tatgth Gn) upper Height (R) Larror Height (Kl FNtid t:Alefancy l-) 89.874 1 s688 156.07 8788 B t 8657 0.0968 0.09086 0.074168 168.24 88986 0.1389 48.155 20225 151.42 8788 144.19 0.097076 0.088267 0.076128 179,47 B4A93 0.13084 58.888 25748 148.19 3782.8 150.78 0.08748 0.09$622 OA77826 199.41 64.866 0.12568 84.848 27235 145.88 8728.0 156A8 0.007764 0.087746 OA79565 198.39 85.189 0.11881 79.101 30702 142.77 9727.9 16t.SB aa9796s 0.099707 0980781 406.82 65.343 0.11387 81.818 84158 140.45 8728 186.42 0.098175 0.10158 0982088 214.24 BsA99 0.11009 88.508 87588 188.94 8722.8 170A8 0.088858 0.10829 oA88331 441.88 85.62 0.10682 97.878 41026 188.4 8741 174.41 0.098474 0.10485 0.0845 228AS 85.714 0.10896 105.83 44448 184.61 3719.2 178.07 0.088587 0.10637 DABS802 284.87 65,78Y 0.1014 119.87 47868 132.92 3717.6 181.5 0.088875 0.1078 0.0888rt1 240.37 65.847 OA99087 122.1 51281 181.84 87i8S 184.94 0.098489 0.10919 0989'881 248.08 85.692 OA97016 18021 54690 128.64 3714.4 187.77 0.088781 0.11048 0.088571 291.55 86.928 0.085112 198.82 S808S 128A2 37t3 190.86 0.098808 0.11172 0.089489 458.79 BS.BSS 0.088888 148A4 8149i' 147.07 8711.8 188Ai 0.098824 0.11281 0.080829 26152 65.978 OA91747 154.51 64896 125.78 3710,8 186,04 0.038824 0.11405 9.09tt5 488.89 65981 0.080844 18129 88494 124.64 8709.1 198.66 0.098812 0.11514 0.081988 471.85 66Ag/ OAB8889 17058 71687 128.88 5707.9 200.87 0.088787 0.11819 OA82889 29'5.88 66.009 OAB7S2S 178.76 96080 122.4 89089 208.26 0.098751 0.1172 OA98416 X0.26 88A18 0.068491 186.84 78471 121.09 8705.7 205.52 0.088707 0.11817 OA84118 2845 BBA18 0.085126 184.81 81880 120.02 8704.8 207.87 0.098666 0.11911 OA9478 E86.68 66A18 0.064026 40287 85248 118.N 87085 208.75 0.088588 0.12002 OA96442 29284 68A17 0.082882 211.04 88037 117.98 8702.5 211.78 0.098886 0.1209 0.096075 286.34 86A17 0.00199 419.1 82024 117.02 87015 218.71 0.088468 0.12178 OA8888s 800.94 66A17 OA8108 229.17 85410 118.08 8700.8 213.8 0.098999 0.12289 0.097E79 804.08 68.017 0.080161 285.28 98796 116.18 8899) 217A8 0.098845 0.14599 0.097856 507.88 85.017 0.078284 24208 tA187ei05 114.87 8698,9 218,85 0.088228 0.12402 OA88304 810.68 86.017 0.078S7S 248.87 1A4SSa+OS 113.82 8898.2 440A8 0.09814 0.12488 0.09878 x18.6 88.017 0.071899 PROPPANT TRANSPORT SOLUTION Avg. Inke EOJ Total 8uap. f3enk Cbaure Prop Prop Prop ConW Tkne Diafan0e Width Cerra Cane. Haight Haight HNght Tknc Height Perm W&Ig1 ArN • (min) Nq An) (i~9aq (Dmv9aq (h) (A) (fU l~n) (fU (~) {M) ll~') STAQE 1 417.77 420.48 0 1 1 0 0 0 22.851 0 0 0 0 228.88 207.81 OA2678 1 1 177.78 O 0 22.961 0 0 0 0 448.87 0 0.077681 1 1 878.8E 0 0 22.851 0 0 0 0 f=luki in)actad fefors time =217.77 (min) Is bas dub to Isalmff A apurl The vak~me a/ Auk! b eaaunt for fhie lose !e 8.146S8a+04 (U.S. San Propped Length 0 (in Avg. FibaGS'e Conduotivhy 0 (~) Alm. f°rllgttre Condugtvhy 0 Avg. Fracture PemteaWbty 0 (md) Avg. Praelure ConcJAroa 0 (bxn/A~ Propped FFadtO+e Volume 0 ProppaM pisplaeamaM l Looatlon Soh $ BCre6h~dt Distance Distance Scree n-oul ScfesmOMt From to Flom to () (-) (A) (fq (A) (~) 1 NO 0 220.48 For a bbnkitg fluid, the 8creert•oW di6tance Only raptttsenta the propped pack volume (di9lance~. FLUIp LSAK-0FF SOLUTION InJ. Leakotf n' a! K' at Time Rafe Rate Inlet Inks (min) (opa+) (bpm) (~) lM+~"n~~I 0.067741 10 8.2.989 OA189 0.08488 OA8924 10 4.495 0.4188 0.08488 • 0.14702 10 4.7727 OA189 0.08488 0.22111 10 6.1881 OA189 OA5488 Oa97s8 10 5.5729 OA189 0.08488 OA5028 10 6.9122 0.4189 0.03488 osee44 10 6.9354 v.4139 D.o5ad6 tr-tr laarns9e _ 8 b ' d NO I 1d~101dX3 dS WtiBb : 88 b6 . SZ 1~0 OCT 25 '94 08~49AM BP EXPLORATION •6- P.5 4l6t1CZ/OL LL -t 1r~ u 88b10'0 BB L4'0 4L9Y8 OL L8'96L ee-$0'p 6644'0 6t9b'8 OL 90'ZbZ • 98410'0 88L4'0 L866'6 OL 13'913 99Ig0'0 81L4'0 9Z4Y8 OL Lt'LZS e9reo•o e1Lro s9er'c of c6La 68460'0 81LY0 Bdb'8 OL i0'LLZ 98610'0 66LY0 5830'6 OL L6'302 89080'0 88LY0 9bLb'A OL L8'484 98610'0 86LY0 9906'8 0L 09'99L 890Lb'0 6E LYO 6L81'8 OL 4L'8tL 98b10'0 81LY0 895'8 OL 89'OlL 89010'0 69L4'0 2098'6 OL 9'~L 89410'0 85LY0 4886'8 OL L9.09L 881'80'0 66 LYO b95S'8 OL Z6'9bL 88660'0 85LY0 BL66'8 OL 38'81L 88060'0 811Y0 LSSC'8 OL LSOBL 88680'0 85LY0 6!38'8 OL L'33L 89460'0 6BLY0 801'8 OL 18'14! 88610'0 81LY0 8!63'8 OL S8'90L 88060'0 6914'0 9412'6 OL 919'!9 98b~'0 86 Lb'0 89SZ'8 OL 809'68 98680'0 68!4'0 0593'6 OL 9L6'L9 88080'0 89Lb'0 tOLZ'8 OL 404'81 99410'0 684b'0 4L9L'8 OL 408'19 98450'0 68!0'0 80!'6 OL 96S'99 88060'0 BCLYO 8980'8 OL SSt'9b 88410'0 89!4'0 L$ZO'B 0L 419'65 98480'0 BB4r0 [056'8 Ot 10'LO 88410'0 88 Lb'0 ZL9L'8 OL b49'ZZ ggyg0'0 6614'0 5898'8 OL 6L0'0L 994eo'o 814b'o x9ce'e oL eez•a e945o•0 66L0•o LOeL•9 of Lee6•e 9941ao 914YO Loce•e oL las9's 98000'0 66 Lr0 B665'L 01 Z480"3 89690'0 88!6'0 ZS9L'1 OL 1SL9'L 88b80'0 65Lr0 938x'8 Ot 6090'! 4alul Lal~l a~ ~!! aWll te,~l id ~~ 41o~e1 'h4 ~ i • • a Stress Prole 3000 3200 3400 360D 3BUD ~/ ~i 4000 ~ 4200 z 0 H 4400 0 J W 4600 00 4800 7 m 5000 ~ 2000 2,500 3000 3500 4000 m Horizontal Stress {psi) Min . • ~~ „~:,~„~. • • • Net Pressure vs Time 200 190 /1 •~ 1eo ~ 170 ~ 160 a ,50 z ,40 130 120 71a 0 30 60 9Q 120 150 180 210 240 270 Time (min) i pRilUGllti71QiWIBW • • • Fracture Profiles (Scaled) 4300 4350 4400 ~1 4450 ~..~ .~ 4500 i--~ ~i 4550 4600 4650 4700 0 ~..~,,,,,~„Q. 50 100 150 200 250 300 350 400 450 500 550 600 Length (ft) 0 • FORM 925307 IRev 2x81} Acoustic Cement Bond Lo 9 V`DL Gamma Ray DRESSER ' ~ (.~ ~ \µ~'~`-'7 ~``~~--pp ~ ~ ~ FILE NO. COMPANY __ UNION U I L C01~1PANY OF CAL I FORN I A API NO. WELL Ku 11-17 FIELD KENA I. GAS FIELD ___ COUNTY KENA I STATE ALASKA _ LOCAT{ON: Other Services 768' s. ~ 631' W. OF N.E. CORNER SEC 18 1V,~P T4N RGE R 1 1 W Permanent Datum G . L . Log Measured from K • B • , Drilling Measured from K • B • _._ Date -_ - __ _ CSG. RECORD Run No. -_ WO _- Size_ Service Order No. 29029 Wt./Fi. Depth -Driller 5264' Grade Depth -Logger 5253' Type Joint Bottom Logged Int. 5246' Top - - _ _ Top Logged interval 3_0.00' Bottom _ Ft. Measured ~ 22+6' Type Fluid in Csg. U D Type Cement Fluid level _ -FULL _ Vol. of Cement Max. Temp. Deg. F. . A . Additive Tool Series No. 1 0$ M °i° Additive Tool Diam. __ 3 5 / $" Retarder _ Standoff Size ENT. °% Retarder Logging Speed 0 FPM 'Slurry Wt. RIA Log Type ~ . R . Water Loss T.C. Drig. Mud Type Sens. Setting ~_ 81 _ Drig. Mud Wt. API Units/Div. __ _ _ _ Truck or Unit No. __ 00 Started Pumping 9 ---- Location ._` ENA I_______ Plug on Bottom_ Opr_ Rig Timeu _ 6 H RS .. _-.__ - Pres_Released Recorded by _ _ BARKER Started Bond Log witnessed by MR . ABERNATHY , Finished Bond Lc Elev. 68.0' KaV~ 84.0' 16 Ft. Above Permanent Datum DF _ GL ~. 68.0' ' Surface Protection Production Liner ' _ 1 ~/8" _-$/8" __-~- 6111 4711 i -~- SURFACE SURFACE-+--__„ 9 9 ~! ~ -- - Z~ -~ ----- .~-------- PRIMARY CEMENTING DATA -~- _ iCLASS _G--~ --- ___-_ , - 0 S X -+ ------ _ 1:0:21 G~L/~i KCL~ 1~R-5/.2%D-16 PRIMARY CEMENTING PROCEDURE 23:~00 2_A__lE_2 Preceding Fluid__ 200' -t- 2-12 Vol. Bbls. ! Returns: Full Partial None - --~- O1 ~ ~ _---t---- --- 2- 1 9 ~ PIPe Rot. During Pumping: Yes No 0] : 3 2-1 9 ; Pipe Rot. After Plugdown: Yes No