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Home My WebLink AboutAIO 008 e e 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. 8 I () 0 08 Order File Identifier Organizing (done) ~wo-sided 1111111111111111111 o Rescan Needed 11111111I1111111111 RES CAN ~olor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) o Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Dale If/71a /ç¿ I I Daletfhlo~ / o Other:: BY: ~ Isl wtP Project Proofing 1111111111111111111 BY: ~ Isl tl1P Date: + = TOTAL PAGES--1!L3 (Count does not include cover sheet) 151 Scanning Preparation BY: {)f£J Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY ~ Dale 4-/7/0" Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 1/111111111111 "III NO Isl VijP NO BY: Maria Date: Isl 111111111111/1 IIIII Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 11/11111111I II1IIII 10/6/2005 Orders File Cover Page.doc • • INDEX AREA INJECTION ORDER #8 Middle Ground Shoal Dillon Platform 1. August 29, 1986 Amoco's Supplemental Data on Waste Disposal Horizons AIO Application 2. September 30, 1986 Ltr from Amoco to AOGCC re: request 3. October 6, 1986 Ltr from Amoco to AOGCC referencing 9/30/86 ltr 4. November 4, 1986 Ltr from US EPA re: termination of EPA Rule Authorization for injection wells 5. June 22, 1995 Internal memo re: Unocal's request to dispose of domestic waste 6. June 27, 1997 Ltr from AOGCC to DEC 7. March 10, 1995 Ltr from Mike Tauriainen to AOGCC re: Unocal conceptual plan 8. May 1, 1995 Ltr from DEC to Unocal re: plan 9. June 8, 1995 Mike Tauriainen response to DEC's ltr 10. January 23, 2003 Unocal application for temporary disposal well Di -12, 11. February 13, 2003 e -mail information from Unocal re: temporary disposal Request 12. September 27, 2004 Public Notice to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells 13. March 21, 2006 Chevron's description of proposed work on Dillon Platform in 2006 and Future 14. March 23, 2006 AOGCC response to Chevron's letter of 3/21/06 15. June 21, 2006 E -mail from AOGCC to Unocal re: Treated WW for FOR 16. May 10, 2007 Chevron's request for Administrative Approval for Dillon Platform 17. UIC Manager backup information 18. May 17, 2007 AOGCC decision that an Administrative Approval is not Necessary 19. September 3, 2009 Union's request for Administrative Approval to utilize S MGS Unit #14 as a temporary disposal well (aio8 -004) 20. November 23, 2009 Unions e -mail and attachments re: Di -14 Post Injection Report 11 -23 -09 21. March 8, 2011 Union's request for Admin Approval (AIO 8.005) 22. April 26, 2011 Email re: MIT MGS 16, 17 23. August 15, 2011 Letter to UNOCAL re:MIT Variance while injecting Approved Wastes Area Injection Order #8 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE REQUEST OF AMOCO ) PRODUCTION COMPANY for ) an Area Injection Order ) for the portion of the ) Middle Ground Shoal Field ) developed by Dillon Platform) Area Injection Order No. 8 Southern Portion of Middle Ground Shoal Field September 4, 1986 IT APPEARING THAT: 1. Amoco Production Company requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within a portion of the Middle Ground Shoal Field for purposes of enhanced hydrocarbon recovery and fluid disposal. 2. Notice of an opportunity for a public hearing on August 30, 1986, was published in the Anchorage Daily News on July 31, 1986. 3. Neither a protest nor a request for a public hearing was timely filed. Accordingly the Commission will, in its discretion, issue an order without a public hear- ing. FINDINGS: 1. An order permitting the underground injection of fluids on an area basis, rather than for each injection well individually, provides for efficiencies in the adminis- tration and surveillance of underground fluid injection operations. 20 AAC 25.460 provides the Commission with the authority to issue an order governing underground injection operations on an area basis. 2. The portion of the Middle Ground Shoal Field developed by Amoco's platform Dillon constitutes a compact "project area" which can readily be described by governmental subdivisions. Amoco is the sole operator of this Project Area. t., ~ {, . 1\'; ., i' Pf/ Area Injection Order No. 8 Page 2 September 4, 1986 3. The Project Area encompasses approximately the southern one-fourth (1/4) of the Middle Ground Shoal Field. The Project Area includes all existing injection wells and injection well sites planned for enhanced recovery of oil from that portion of the MGS A, B, C, D, E, F, and G Oil Pools. The Project Area also includes all well sites planned for disposal by injection into shallower Tertiary strata of oil field waste fluids which may develop from the operation of this portion of the field. 4. The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the Middle Ground Shoal Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c). 5. Less stringent requirements for well construction, operation, monitoring, and reporting of injection operations may be more appropriate than would be required when injection occurs into, through or above portions of aquifers not exempted. 6. The vertical limits of injection strata and confining formations may be defined in the Pan American Petroleum Corporation State 17595 well No.4. 7. The strata into which fluids are to be injected will accept fluids at injection pressures which are less than the fracture pressure of the injection strata and their confining formations. 8. Statewide regulations and conservation orders govern field operations except as modified by this order. 9. To ensure that fluids injected are confined to in- jection strata, the mechanical integrity of injection wells should be demonstrated periodically and monitored routinely for disclosure of possible abnormalities in operating conditions. 10. Injection wells existing on the date of this order were constructed and completed in accordance with regu- lations which conform to the requirement of 20 AAC 25.412. o G 7n01 Area Injection Order No.8 Page 3 September 4, 1986 NOW, THEREFORE, IT IS ORDERED THAT the rules hereinafter set forth govern Class II underground injection operations in the following described area referred to in this order as the affect- ed area: SEWARD MERIDIAN T7N R13W Section 1 : NW %. Section 2 : all. Section 3: all. Section 10 : N ~ and SE %. 2 Section 11: NW %. Section 27: SW %. Section 34: all. Section 35: all. Section 36: W ~. T8N R13W Rule 1 Authorized Injection Strata for Enhanced Recovery Within the affected area, non-hazardous fluids may be injected for purposes of pressure maintenance and enhanced oil recovery into strata defined as those strata which correlate with the strata found in the Pan American Petroleum Corporation State 17595 well No.4 between the measured depths of 5,300 feet and 9,215 feet. Rule 2 Authorized Injection Strata for Disposal Within the affected area, non-hazardous oil field fluids may be injected for the purpose of fluid disposal into strata defined as those strata which correlate with the strata found in the Pan American Petroleum Corporation State 17595 well No.4 in the measured depth intervals of 2620 feet to 3090 feet and 4330 feet to 4955 feet. Rule 3 Fluid Injection Wells The underground injection of fluids must be: 1) through a new well that has been permitted for drilling as a service well for injection in conformance with 20 AAC 25.005; 2) through an existing well that has been approved for conversion to a service well for injection in conformance with 20 AAC 25.280; or 3) through a well that existed as a service well for injection purposes on the date of this order. ri ( /(\\1'1 Area Injection Order No.8 Page 4 September 4, 1986 Rule 4 Monitoring the Tubing/Casing Annulus Pressures The tubing/casing annulus pressure of each injection well must be checked weekly to ensure there is no leakage and that it does not exceed a pressure that will subject the casing to a hoop stress greater than 70% of the casing's minimum yield strength. Rule 5 Reporting the Tubing/Casing Annulus Pressure Variations Tubing/casing annulus pressure variations between consecutive observations need not be reported to the Commission. Rule 6 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission which ensures that the tubing/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, which ever is greater, but not to exceed a hoop stress greater than 70% of the casing's minimum yield strength, must be held for 30 minutes with no more than a 10 percent decline. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Rule 7 Well Integrity Failure Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must immediately cease injection, notify the Commission, and obtain approval for corrective action. Rule 8 Plugging and Abandonment of Fluid Injection Wells An injection well located within the affected area must not be plugged or abandoned unless approved by the Commission in accor- dance with 20 AAC 25.105. ~ '\ , , f\ ~\ 'I \\ '.' ¡ ;' Area Injection Order No. 8 Page 5 September 4, 1986 Rule 9 Administrative Relief Upon request, the Commission may administratively amend any rule stated above as long as the operator demonstrates to the Com- mission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. DONE at Anchorage, Alaska and dated September 4, 1986. Commission Commission JVpI W. W. Barnwe Alaska Oil & Commission 'I·. ~5 ; 'I"~ ,\ (. .1~ () \ 1"1 \:. ( ':¡, Telecopy No. (907) 276-7542 October 28, 1986 ADM I N I S T RAT I V E A P PRO V A L N O. 8.1 Re: Amend Rule 7 of Area Injection Order (AIO) No. 8 Mr. W. G. Smi th District Manager Amoco Production Company P. O. Box 100779 Anchorage, AK 99510-0779 Dear Mr. Smith: The Commission has determined tha.t Rule 7 of AlO No. 8as set forth is unclear as to the Commission's intent. Therefore, Rule 7 is amended to read: Rule 7 Well Integrity Failure Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must [IMMEDIATELY CEASE INJECTION,] notify the Comnlission on the first working day following the observation, [AND] obtain Commission approval [FOR CORRECTIVE ACTION] of a Ian for corrective action and when an USDW is not endangere , 0 tain Commission approva to continue injection. S inc.~ r e t Y ---'ì~, / I¡I-) )~' ~. i ",///." . f/ ,/ i/f· , ('--__~ ' I,/-. /"-f~;~l;'f+ C. V. Chatterton Chairman jo/3.AA AlO 8.1 \"(·l\~\W,W:'~L) ,;~VQ"'~" .~~ (j'O ")Qf\"1 I, .) \ " ' ,~ :,.-- , û L_ v , ) rrr [-6 IK\ n ® ~ ~ lb~ "J 1 /Jt I1lflj L~ -!.l LIü ) AI,ASKA. OILA5D GAS CONSERVATION COJDIISSION / / FRANK H. . MURKOWSK', GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 8.2 Re: The application of Union Oil Company of California to inject approved wastes from the Dillon Platform for the purpose of disposal into the stratigraphic interval authorized for enhanced recovery by Area Injection Order No.8. Philip M. Ayer Advising Petroleum Engineer UNOCAL Corp. P. O. Box 196247 Anchorage, Ak 99501 Mr. Ayer: In correspondence dated January 23, 2003 you state that Unocal considers production operations from the Dillon Platform to no longer be economically viable. Oil production on the platform has been shut in since December 8, 2002. Unocal intends to clean the surface equipment from January through April 2003 and does not intend to resume oil production operations on this structure. Unocal estimates 50,000 barrels of non-hazardous Class II fluids will be generated by cleaning operations on Dillon. The fluid is expected to be primarily comprised of unfiltered inlet water, produced water, produced oil, sludge, triethyleneglycol, paraffin and asphaltenes. Unocal applied in the above referenced correspondence to dispose of these fluids into two existing Dillon Platform wells. Area Injection Order No. 8 authorizes injection in the Southern Portion of the Middle Ground Shoal Field. Disposal injection is authorized by this order in the upper portion of the Tyonek Formation. Currently no wells on the Dillon Platform are completed in the disposal interval. Rule 9 of Area Injection Order No.8 allows the Commission to administratively amend any rule in the order as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. <"ii'" /\ I' rIG\U'I~'" 0~.¡\\~l'\-tJ j\Jt:~,j (; e 20D/,i Philip M. Ayer AIO 8.2 January 29, 2003 Page 2 of2 ) Unocal has demonstrated Dillon Platfonn wells Di-12 and Di-14 have mechanical integrity suitable for disposal injection operations. Di-12 and Di-14 are respectively, a decommissioned waterflood injector and a depleted oil producer. The primary candidate for disposal operations is the Di-12 well with well Di-14 intended as a back-up. Disposal operations in these wells will not cause waste due to the limited volume of injectant and the swept or depleted condition of the reservoir adjacent to these wells. The portion of aquifers beneath Cook Inlet described by a ~ mile area beyond and lying directly below the middle Ground Shoal Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c). Pursuant to Rule 9 of Area Injection Order No.8 Unocal is authorized to conduct disposal injection operations in Dillon Platfonn wells Di-12 and Di-14 within the MGS A, B, C, D, E, F, and G Oil Pools. The total volume authorized for disposal is 50,000 barrels. DONE in Anchorage, Alaska this 29th of January 2003. i/"-J ~/,.~ ,i. ...... // l /,' ~.",. ¡I LI" ,,".>~.I¿f/., " ,. ... ":'1 :~:7// '/ '~/~,/ Iianiel T. S'éamount, Jr. Commissioner .~?-~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION . .,f;~J~\OIL, ~I) 0 'ì~~'\ \ III..~,~~. ¡ (, ~.~~~,;J '0', J t~'t-<'::;?¡~i~ \rè'lij.?1;1·~~1 J<':';~i :\ :""\ \?7 'N ¡;: '~\ ~;'\'~:~:<Í"~;;;;il~~~: ø ð . '. ,:, ',' ~ i" ¡ 1. ""'" . À't'·~- f t- '~~f:~~~~iiik~!~!!':i4;;tl ". ..'.... ~:~. '. '.. n c ZODI~. ) ] rç:fò\ n r{;\~? [~ ~ ~ If W LLLi-ûJ)~Lrü ) AI,ASKA OIL A5D GAS CONSERVATION COMMISSION I I / / FRANK H. MURKOWSKI, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. AIO 8.3 Philip M. Ayer Advising Petroleum Engineer UNOCAL Corp. P. O. Box 196247 Anchorage, Ak 99501 Re: The application of Union Oil Company of California to inject approved wastes from the Dillon Platform for the purpose of disposal into the stratigraphic interval authorized for enhanced recovery by Area Injection Order No.8. Dear Mr. Ayer: On January 29, 2003, Unocal was granted approval to dispose of approved wastes developed during the cleaning of the production vessels and wells on Dillon Platform into Dillon wells Di- 12 and Di-14. Please reference Administrative Approval No. AIO 8.2. Unocal has submitted sundry approval requests for the identified wells and the specific approval for Di-12, 303-021 was given on January 29, 2003. As the approval for Di-14 was processed, it was brought to the Commission's attention that "deck drainage" resulting from rain and snow falling on the platform was a fluid that might also require disposal. Rule 9 of Area Injection Order No.8 allows the Commission to administratively amend any rule in the order as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. The Commission has previously found that storm water collected in the drain system of another platform was suitable for disposal in a Class II-D well (DIO 22.001, June 19, 2002). Unocal has previously demonstrated Dillon Platform wells Di-12 and Di-14 have mechanical integrity suitable for disposal injection operations. In this particular case, deck drainage fluids had not been specifically identified in AlO 8.2, however, the Commission did not specifically intend to exclude such fluids from the disposal authorization. Adding deck drainage to the previously approved disposal fluids in these wells will not adversely impact the reservoir or present any increased risk to the environment. The portion of aquifers beneath Cook Inlet described by a ~ mile area beyond and lying directly below the middle Ground Shoal Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c). r H""" - -- 1'\' 1'~ n (" (Jrj fì ,fj se./\\\h',\~"¡ I ..' ' • . ~ o ~ ~ ~ SEAN PARNELL, GOVERNOR ~-7~ ~i~ ~ ut~.7 333 W. 7th AVENUE, SUITE 100 COI~TSERQATIOI~T CODII-IIS51O1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 8.004 Mr. Larry Greenstein Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Re: South Middle Ground Shoal (S MGS) Unit 14 (PTD 1750660) Request for Ad- ministrative Approval Middle Ground Shoal Oil Pool, Dillon Platform Dear Mr. Greenstein: In accordance with Rule 9 of Area Injection Order (AIO) 008.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby approves Union Oil Company of California (Union)'s request for administrative approval to inject non- hazardous oil field fluids into the subject well. A wellbore temperature survey indicates that well S MGS Unit 14 exhibits a production casing / liner leak, and thus does not meet the mechanical integrity requirement of AIO 008.000. The Commission finds that Union does not intend to repair the well at this time. However, injected fluid appears to be confined to subsurface strata that are approved by AIO 008.000 to receive injected fluids. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to inject non-hazardous oil field fluids in S MGS Unit 14 is conditioned upon the following: Union shall monitor wellhead pressures and injection rate continuously during in- j ection; ~ 2. Union shall submit to the AOGCC a post-injection report of injected fluid source, type, and volume; 3. Union shall limit the inner annulus pressure to 2000 psi; 4. Union shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 5. After well shut-in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and AIO 8.004 • • September 15, 2009 Page 2 of 2 6. Union shall perform and submit to the AOGCC a post-injection wellbore tem- perature survey. DONE at Anchorage, Alaska and dated September 15, 2009. utL ~,~;. a~~ ~ ~ ~ ~ -~,a".z ~ ~ ~~~ ~t .~ , ~ . . . ie . Seamount, Jr. Cathy P Foe ter "~"s,~; ~ ai an Commissioner ~~~~~~i~;w ~•.~ ~,._______, 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 fite 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 re- consideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Com- mission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by in- action, 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 re- consideration 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 re- consideration. 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. • • Page 1 of 1 Colombie, Jody J (DOA) From: Seamount, Dan T (DOA) Sent: Tuesday, September 15, 2009 3:55 PM To: Colombie, Jody J (DOA) Subject: Re: aio8 Approved Sent from my iPhone On Sep 15, 2009, at 3:54 PM, "Colombie, Jody J(DOA)" <jody.c~lombie cr alaska.~;oy> wrote: Jody J. Colombie Special Assistant ~Ila,ska Oil c~nd Gas Conservation Con~mission 333 West 7th Avenue, Suite 100 Ancho~~age, AK 99501 (907)793-122I (phone) (907j276-7542 (fcrx) <aio8-004.doc> 9/15/2009 ~ Page 1 of 1 ~ Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Wednesday, September 16, 2009 9:34 AM Subject: aio8-004, aio2b-044 and co406b-009 Attachments: aio8-004.pdf; aio2b-44 and co406b-009.pdf BCC:'Aaron Gluzman'; caunderwood@marathonoil.com; 'Dale Hoffman'; Fridiric Grenier; 'Gary Orr'; Jerome Eggemeyer; 'Joe Longo'; 'Lamont Frazer'; Marc Kuck; 'Mary Aschoff; Maurizio Grandi; P Bates; Richard Garrard; 'Sandra Lemke'; 'Scott Nash'; 'Steve Virant'; 'Wayne Wooster'; 'Willem Vollenbrock'; 'William Van Dyke'; Woolf, Wendy C(DNR); 'Anna Raff ;'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Blaine Campbell'; 'Bowen Roberts'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol smyth'; 'Charles O'Donnell'; Chris Gay; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Gorney'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; Deborah Jones; Decker, Paul L(DNR); 'doug_schultze'; 'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; 'Gregg Nady'; 'gspfoff; 'Hank Alford'; 'Harry Engel'; 'jah'; 'Janet D. Platt'; 'jejones'; 'Jerry Brady'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; 'Jon Goltz'; Joseph Darrigo; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Elowe'; 'Laura Silliphant'; 'mail=akpratts@acsalaska.net'; 'mail=foms@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marquerite kremer'; Melanie Brown; 'Michael Nelson'; 'Mike Bill'; 'Mike Jacobs'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'inkin7200'; 'Nan Thompson'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Winslow'; 'peter Contreras'; Rader, Matthew W(DNR); Raj Nanvaan; 'Randall Kanady'; 'Randy L. Skillern'; 'Rob McWhorter'; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Province'; 'Rudy Brueggeman'; 'Sandra Pierce'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; Shellenbaum, Diane P(DNR); Slemons, Jonne; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Ted Rockwell'; 'Temple Davidson'; Teresa Imm; 'Terrie Hubble'; 'Thor Cutler'; 'Tim Lawlor'; 'Todd Durkee'; Tony Hopfinger; 'trmjrl'; 'Walter Featherly'; Walter Quay Attachments:aio8-004.pdf;aio2b-44 and co406b-009.pdf; Re-send, as the first file was too large for most of you to receive. Jody J. Colornbie Special Assistant ~llask-a Oil and Gas Conservation Cofnr~zission 333 West 7th Avenue, Suite 100 Anchorage, AK 9.9501 (90?)793-IZZ1 (phone) (907)276-7542 (f'c~) 9/16/2009 ~ . Page 1 of 1 Colombie, Jody J (DOA) From: Colombie, Jody J (DOA) Sent: Wednesday, September 16, 2009 8:50 AM Subject: aio8-004 and aio2b-0044, co406b-009 Attachments: aio2b-44 and co406b-009.pdf; aio8-004.pdf BCC:'Aaron Gluzman'; caunderwood@marathonoil.com; 'Dale Hoffman'; Fridiric Grenier; 'Gary Orr'; Jerome Eggemeyer; 'Joe Longo'; 'Lamont Frazer'; Marc Kuck; 'Mary Aschoff; Maurizio Grandi; P Bates; Richard Garrard; 'Sandra Lemke'; 'Scott Nash'; 'Steve Virant'; 'Wayne Wooster'; 'Willem Vollenbrock'; 'William Van Dyke'; Woolf, Wendy C(DNR); 'Anna Raff; 'Barbara F Fullmer'; 'bbritch'; 'Bill Walker'; 'Blaine Campbell'; 'Bowen Roberts'; 'Brad McKim'; 'Brandon Gagnon'; 'Brian Gillespie'; 'Brian Havelock'; 'Brit Lively'; 'Bruce Webb'; 'buonoje'; 'Cammy Taylor'; 'Cande.Brandow'; 'carol smyth'; 'Charles O'Donnell'; Chris Gay; 'Cliff Posey'; 'Dan Bross'; 'dapa'; 'Daryl J. Kleppin'; 'David Brown'; 'David Gorney'; David House; 'David L Boelens'; 'David Steingreaber'; 'ddonkel'; Deborah Jones; Decker, Paul L(DNR); 'doug_schultze'; 'Evan Harness'; 'eyancy'; 'foms2@mtaonline.net'; 'Francis S. Sommer'; 'Fred Steece'; 'Garland Robinson'; 'Gary Laughlin'; 'Gary Rogers'; 'Gary Schultz'; 'ghammons'; 'Gordon Pospisil'; 'Gregg Nady'; 'gspfoff; 'Hank Alford'; 'Harry Engel'; 'jah'; 'Janet D. Platt'; 'jejones'; 'Jerry Brady'; 'Jerry McCutcheon'; 'Jim Arlington'; 'Jim White'; 'Jim Winegarner'; 'Joe Nicks'; 'John Garing'; 'John S. Haworth'; 'John Spain'; 'John Tower'; 'John W Katz'; 'Jon Goltz'; Joseph Darrigo; 'Julie Houle'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; knelson@petroleumnews.com; 'Krissell Crandall'; 'Kristin Elowe'; 'Laura Silliphant'; 'mail=akpratts@acsalaska.net'; 'mail=foms@mtaonline.net'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley'; 'Mark Kovac'; 'Mark P. Worcester'; 'Marquerite kremer'; Melanie Brown; 'Michael Nelson'; 'Mike Bill'; 'Mike Jacobs'; 'Mike Mason'; 'Mikel Schultz'; 'Mindy Lewis'; 'MJ Loveland'; 'mjnelson'; 'mkm7200'; 'Nan Thompson'; 'Nick W. Glover'; NSK Problem Well Supv; NSU, ADW Well Integrity Engineer; 'Patty Alfaro'; 'Paul Winslow'; 'peter Contreras'; Rader, Matthew W(DNR); Raj Nanvaan; 'Randall Kanady'; 'Randy L. Skillern'; 'Rob McWhorter'; rob.g.dragnich@exxonmobil.com; 'Robert Campbell'; 'Robert Province'; 'Rudy Brueggeman'; 'Sandra Pierce'; 'Scott Cranswick'; 'Shannon Donnelly'; 'Sharmaine Copeland'; Shellenbaum, Diane P(DNR); Slemons, Jonne; 'Sondra Stewman'; 'Sonja Frankllin'; 'Stan Porhola'; 'stanekj'; 'Steve Lambert'; 'Steve Moothart'; 'Steven R. Rossberg'; 'tablerk'; 'Tamera Sheffield'; 'Ted Rockwell'; 'Temple Davidson'; Teresa Imm; 'Terrie Hubble'; 'Thor Cutler'; 'Tim Lawlor'; 'Todd Durkee ; Tony Hopfinger; 'trmjrl'; 'Walter Featherly'; Walter Quay; Aubert, Winton G(DOA); Birnbaum, Alan J(LAW); Crisp, John H(DOA); Darlene Ramirez; Davies, Stephen F(DOA); Fleckenstein, Robert J(DOA); Foerster, Catherine P(DOA); Grimaldi, Louis R (DOA); Johnson, Elaine M(DOA); Jones, Jeffery B(DOA); Laasch, Linda K(DOA); Mahnken, Christine R(DOA); Maunder, Thomas E(DOA); McIver, Bren (DOA); McMains, Stephen E(DOA); Noble, Robert C(DOA); Norman, John K(DOA); Okland, Howard D(DOA); Paladijczuk, Tracie L(DOA); Pasqual, Maria (DOA); Regg, James B (DOA); Roby, David S(DOA); Saltmarsh, Arthur C(DOA); Scheve, Charles M(DOA); Schwartz, Guy L(DOA); Seamount, Dan T (DOA) Attachments:aio2b-44 and co406b-009.pdf;aio8-004.pdf; Jocly J. Colornhie Specia! Assistunt Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suzte 100 ~tnchorage, AK 99501 (907)793-1221 (phone) (907)276-75d2 (f'ax) V" '' n~ 1/~ ~~/ lN`" ~""- / V _ GJ ~~ ~ ~ (~ ~ ~ ~~ ~~ 9/ 16/2009 ~ • Mary Jones David McCaleb Cindi Walker XTO Energy, Inc. IHS Energy Group Tesoro Refining and Marketing Co. Cartography GEPS Supply & Distribution 810 Houston Street, Ste 2000 5333 Westheimer, Ste 100 300 Concord Plaza Drive Ft. Worth, TX 76102-6298 Houston, TX 77056 San Antonio, TX 78216 George Vaught, Jr. Jerry Hodgden Richard Neahring PO Box 13557 Hodgden Oil Company NRG Associates Denver, CO 80201-3557 408 18th Street President Golden, CO 80401-2433 PO Box 1655 Colorado Springs, CO 80901 Mark Wedman Schlumberger Ciri Halliburton Drilling and Measurements Land Department 6900 Arctic Blvd. 2525 Gambell Street #400 PO Box 93330 Anchorage, AK 99502 Anchorage, AK 99503 Anchorage, AK 99503 Baker Oil Tools Ivan Gillian Jill Schneider 4730 Business Park Blvd., #44 9649 Musket Bell Cr.#5 US Geological Survey Anchorage, AK 99503 Anchorage, AK 99507 4200 University Dr. 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 Inc. Fairbanks, AK 99706 Fairbanks, AK 99707 PO Box 58055 Fairbanks, AK 99711 North Slope Borough PO Box 69 Barrow, AK 99723 ~ D I~ • . �, `� �� a SEAN PARNELL, GOVERNOR O 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 AREA INJECTION ORDER 8.005 Mr. Tim Brandenburg Drilling Manager Union Oil Company of California (UNOCAL) P.O. Box 196247 Anchorage, Ak 99501 Re: South Middle Ground Shoal Unit 16 (194 -057) South Middle Ground Shoal Unit 17 (194 -056) Request to Inject Approved Wastes into the Stratigraphic Interval Authorized for Enhanced Recovery by Area Injection Order No. 8 Mr. Brandenburg: In correspondence dated March 8, 2011 UNOCAL requested authorization to use South Middle Ground Shoal Unit (SMGS) wells 16 and 17 for purposes of disposal of liquid wastes generated through well circulation and abandonment. Both wells are on the Dillon Platform. The Commission GRANTS UNOCAL's request. Production operations on Dillon Platform were halted December 8, 2002 when UNOCAL determined that such operations were not economically viable. Area Injection Order (AIO) No. 8 authorized injection of non - hazardous oil field fluids for the purpose of fluid disposal into strata that correlate with those found from 2620' to 3090' measured depth (MD) and from 4330' to 4955' MD in Pan American Petroleum Corporation State 17595 well No. 4. Based in part upon a Commission finding that disposal operations would not cause waste due to the limited volume of disposed fluids and the swept or depleted condition of the authorized reservoir intervals, on January 29, 2003 AIO 8.002 authorized disposal of 50,000 barrels of non- hazardous, Class II fluids generated by cleaning operations on Dillon Platform into the MGS A, B, C, D, E, F, and G Oil Pools, within wells SMGS 12 and SMGS 14. Authorized fluids are unfiltered inlet water, produced water, produced oil, sludge, triethyleneglycol, paraffin and asphaltenes. On March 4, 2003 AIO 8.003 authorized injection of storm water. UNOCAL injected 6,347 and 1,613 barrels of waste fluids into wells SMGS 12 and SMGS 14, respectively, while cleaning surface equipment and performing well work. Deteriorating well performance during the most recent work accomplished in October, 2009 prompts this request for additional Administrative Approval. Wells SMGS 16 and 17 are two of the Dillon Platform's most recently drilled wells, and are open in the Middle Ground Shoal E, F, and G Oil Pools, as are wells SMGS 12 and 14. SMGS 16 and 17 were completed in 1994, and are equipped with tubing and packers. Well operations AIO 8.005 • • April 12, 2011 Page 2 of 3 reports and bond logs have been examined, and both wells are satisfactorily constructed and exhibit mechanical integrity. UNOCAL proposes to perform standard mechanical integrity tests as required by regulation prior to placing the wells in operation. UNOCAL is not requesting an increase in the authorized injected fluid volume. Rule 9 of Area Injection Order No. 8 allows the Commission to administratively amend any rule in the order as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. The portion of aquifers beneath Cook Inlet described by a 1 /4 -mile area beyond and lying directly below the Middle Ground Shoal Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(C). Commission administrative approval to inject the above - specified non - hazardous, Class II oil field fluids into Dillon Platform wells SMGS 16 and 17 within the MGS A, B, C, D, E, F, and G Oil Pools is conditioned on the following: 1. Prior to placing each well into service as a disposal well, UNOCAL shall perform mechanical integrity tests which comport with the requirements of 20 AAC 25.412. The tests should be witnessed by a Commission Inspector; 2. UNOCAL shall monitor wellhead pressures and injection rate continuously during injection; 3. UNOCAL shall submit to the Commission a post- injection report of injected fluid source, type, and volume by well; 4. UNOCAL shall immediately shut in the well and notify the Commission if there is any change in the well's mechanical condition; 5. After well shut -in due to a change in the well's mechanical condition, the Commission's prior approval shall be required to restart injection; and 6. The total remaining authorized disposal volume is 42,000 barrels. DONE at • i chor . • e, Alas a and dated April 12, 2011. a'r�' orman Cathy P /Foerster (W: I missi• • -r Commissioner OIL Al% ,17-41* ct 4. MO 8.005 • April 12, 2011 Page 3 of 3 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: Tuesday, April 12, 2011 2:56 PM To: 'Aaron Gluzman'; Bettis, Patricia K (DNR); caunderwood @marathonoil.com; 'Dale Hoffman'; 'David Lenig'; 'Gary Orr; 'Jason Bergerson'; 'Joe Longo'; 'Kevin Skiba'; 'Lara Coates'; 'Marc Kuck'; 'Mary Aschoff; 'Matt Gill'; 'Maurizio Grandi'; Ostrovsky, Larry Z (DNR); 'Richard Garrard'; 'Sandra Lemke'; 'Talib Syed'; 'Wayne Wooster'; 'William Van Dyke'; Woolf, Wendy C (DNR); '(foms2 @mtaonline.net)'; '( michael .j.nelson @conocophillips.com)'; '(Von.L .Hutchins @conocophillips.com)'; 'AKDCWelllntegrityCoordinator; 'Alan Dennis'; 'alaska @petrocalc.com'; 'Anna Raff; 'Barbara F Fullmer'; 'bbritch'; 'Becky Bohrer; 'Bill Penrose'; 'Bill Walker'; 'Bowen Roberts; 'Brady, Jerry L'; 'Brandow, Cande (ASRC Energy Services)'; 'Bruce Webb'; 'caunderwood'; 'Chris Gay'; 'Cliff Posey'; 'Crandall, Krissell'; 'D Lawrence'; 'dapa'; 'Daryl J. Kleppin'; 'Dave Matthews'; 'David Boelens'; 'David House'; 'David Steingreaber; 'ddonkel @cfl.rr.com'; Delbridge, Rena E (LAA); 'Dennis Steffy'; 'Elowe, Kristin'; 'Erika Denman'; 'eyancy'; 'Francis S. Sommer'; 'Fred Steece'; 'Gary Laughlin'; 'Gary Rogers'; 'ghammons'; 'Gordon Pospisil'; 'Gorney, David L.'; 'Greg Duggin'; 'Gregg Nady'; 'gspfoff; 'Harry Engel'; 'Jdarlington (jarlington @gmail.com)'; 'Jeanne McPherren'; 'Jeff Jones'; 'Jerry McCutcheon'; 'Jill Womack'; 'Jim White'; 'Jim Winegarner; 'Joe Nicks'; 'John Garing'; 'John Katz'; 'John S. Haworth'; 'John Spain'; 'John Tower; 'Jon Goltz'; 'Judy Stanek'; 'Kari Moriarty'; 'Kaynell Zeman'; 'Keith Wiles'; 'Kelly Sperback'; 'Kim Cunningham'; 'Larry Ostrovsky'; 'Marilyn Crockett'; 'Mark Dalton'; 'Mark Hanley (mark.hanley @anadarko.com)'; 'Mark Kovac'; 'Mark P. Worcester; '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'; ' rob.g.dragnich @e)oxonmobil.com'; 'Robert Brelsford'; 'Robert Campbell'; 'Ryan Daniel'; 'Ryan Tunseth'; 'Scott Cranswick'; 'Scott Griffith'; Scott, David (LAA); 'Shannon Donnelly'; 'Sharmaine Copeland'; Shellenbaum, Diane P (DNR); Slemons, Jonne D (DNR); 'Sondra Stewman'; 'Steve Lambert'; 'Steven R. Rossberg'; 'Suzanne Gibson'; 'tablerk'; 'Tamera Sheffield'; Taylor, Cammy 0 (DNR); 'Teresa Imm'; 'Terrie Hubble'; 'Thor Cut ler'; 'Tina Grovier; 'Todd Durkee'; 'Tony Hopfinger'; 'trmjrl'; 'Valenzuela, Mariam '; '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) (lou.grimaldi @alaska.gov); Herrera, Matt F (DOA); Johnson, Elaine M (DOA) (elaine.johnson @ alaska.gov); Jones, Jeffery B (DOA) (jeff.jones @alaska.gov); Laasch, Linda K (DOA) (linda.laasch @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); Pasqua!, Maria (DOA) (maria.pasqual @alaska.gov); Regg, James B (DOA) (jim.regg @alaska.gov); Roby, David S (DOA) (dave.roby @alaska.gov); Saltmarsh, Arthur C (DOA) (art.saltmarsh @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); Shartzer, Christine R (DOA) Subject: AIO 8.005 UNOCAL Attachments: aio 8- 005.pdf S c -in. nth ,s u iktAkcc, o cx vtd, C: onse.v'va;tLon 'c>-rn, no,s,,on (907)793-1223 (907 )276 7542 (fax,) 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 Jerry Hodgden Richard Neahring Mark Wedman Hodgden Oil Company NRG Associates 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. 94 Ct. 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 -2139 Soldotna, AK 99669 -7714 Fairbanks, AK 99701 M N • i 2 I AEFLE tyLnsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMIIIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 August 15, 2011 Mr. Timothy C. Brandenburg Drilling Manager Union Oil Company of California (UNOCAL) P.O. Box 196247 Anchorage, AK 99519 -6247 Re: South Middle Ground Shoal Unit 16 (194 -057) Request for Mechanical Integrity Test Variance for SMGS Unit 16 while Injecting Approved Wastes as Authorized by AIO 8.005 Dear. Mr. Brandenburg: In correspondence dated August 3, 2011 UNOCAL requested a waiver to the Mechanical Integrity Test (MIT) for SMGS 16 as required by AIO 8.005. UNOCAL submitted valid information demonstrating mechanical integrity (MI) by other means. The Commission ACCEPTS UNOCAL's submission. On April 12, 2011, the Commission issued AIO 8.005 granting approval for UNOCAL to employ two shut -in development wells on Dillon Platform for waste liquid disposal during circulation and plugging operations. Production operations on Dillon Platform were halted December 8, 2002 when UNOCAL determined that such operations were not economically viable. UNOCAL was required to demonstrate that the wells had mechanical integrity prior to injecting waste fluids. A standard pressure test of the tubing x casing annulus was successfully accomplished on SMGS 17; however a standard pressure test could not be accomplished on SMGS 16 due to pressure communication between the tubing and annulus. Alternate testing methods can be employed to demonstrate MI. UNOCAL has successfully demonstrated that the production casing of SMGS 16 is competent by setting a deep wireline plug and pressuring the wellbore to 2400 psi. Minimal pressure loss was observed during the 3.5 hour charted observation period. UNOCAL also performed a temperature survey of the well which did not exhibit any thermal anomalies which would indicate the casing was leaking. UNOCAL has complied with the requirements of Condition 1 of AIO 8.005. No variance is necessary. Sincerely, � I Daniel. . eamount, Jr. Chair • • Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, , AK AK 99519 -6247 Tel 907 263 7657 Fax 907 263 78888 4 Email brandenburgt @chevron.com August 3, 2011 -" Mkt Commissioner .. ,.,k. Alaska Oil & Gas Conservation Commission ' ; : ' 4 /;;,: 333 W. 7 Avenue Anchorage, Alaska 99501 l :5 i,; '£ a��I, , I; � Re: Request for Variance of the Mechanical Integrity Test required for Temporary Disposal in Di -16, PTD 194 -057 Dear Commissioner, Union Oil Company of California would like to request a variance of the Mechanical Integrity Test required by the Administrative Approval Area Injection Order 8.005 dated April 12, 2011, for the Dillon Platform, specifically regarding the well SMGS Unit 16 (Di -16), PTD 194 -057. Area Injection Order (AIO) No. 8, approved on December 8, 2002, authorized injection of non- hazardous oil field fluids for the purpose of fluid disposal into specific strata. On January 29, 2003, AIO 8.002 authorized disposal of 50,000 barrels of non - hazardous, Class II fluids generated by cleaning operations on Dillon Platform into the MGS A, B, C D, E, F, and G Oil Pools, within SMGS 12 and SMGS 14. Operations completed in 2009 injected a total of 7,960 barrels into SMGS 12 and SMGS 14, leaving 42,000 barrels for injection under the order. AIO 8.003 was approved on March 4, 2003, which authorizes the injection of storm water. On April 12, 2011, AIO 8.005 was approved and authorized the use of SMGS 16 and SMGS 17 for purposes of disposal of liquid wastes generated through the well circulation and abandonment operations. A Bundle (i.e. jug) MIT was completed on Di -16 on June 20, 2011, confirming the integrity of the casing and packer. Analysis of the static temperature survey completed on July 23, 2011, indicated the casing was not leaking. If approval is granted, Union Oil Company of California is prepared to comply with the remaining conditions of AIO 8.005 including monitoring wellhead pressures and injection rate continuously during injection, submittal of post- injection reports of injected fluid source, type, and volume by well, and will immediately shut in the well and notify the Commission if there is any change in the well's mechanical condition, etc. Please see the attachments containing information per 20 AAC 25.412. Please let us know if we can provide any further information by contacting myself at 263 -7657 or Nigel Bonnett at 263 -7853. Union Oil Company of California / A Chevron Company . • Chairman Daniel T. Seamount, Jr. Alaska Oil & Gas Conservation Commission January 22, 2009 Page 2 Sincerely, fr Timothy C. Brandenburg Drilling Manager Attachments: Di -16 Bundle MIT Test dated 6/20/2011, Di -16 Temperature Survey dated 7/23/2011, Operations Summary, and Well Schematic. Union Oil Company of California / A Chevron Company . • • • 9 Chevro !i i i Dillon Platform Dillon Platform Well Di -16 " Dl _ 16 Last Completed 7 /20/94 Casing and Tubing Detail RHB•TH: 55' 2 B - - Size Type Wt / Grade Top Btm CONN / ID Cement / Other 30" Surface 83' 826sx lead & 630sx tail 18 %" Surface 97.7#/ X -57 Surface 1,132' QTE60 / 17.653" w /additives, good cement returns at surface 18 %V 13 %, 373bbis Lead 1g12.9ppg & 1132 68 #, K -55, 74bbls Tail 15 ppg CaIc.TOC 133/ ®" Intermediate Surface 3,640' K- 55/12.415 @ d N. @782' BTC w /additives, Calculated 13 i" TOC= 762',(IncL =0.61 3840• 163 bbls premium w/ add 9 %" Production 47#/L-80 Surface 10,155' Butt / 8.68" 9115.8ppg, CBL TOC 8,300' 140 bbls @15.8 ppg w/ C8LTOC 7" Liner 32 #/P -110 9,987' 11,703' TKC -BTC /6.094" additives CBL TOC 8300' 10,150' A 1 1 2 Tubing - - � C 3 Y" Production 9.2#, L -80 Surface 9,794' SCBTC / 2.992' Long String/ Internally coated tubing h 2 3 _ 1 G 3 W _ Production 9.2#, L -80 _ Surface 9,785' SCBTC /2.992" Short String i 7 7" TOL Dual String 11 9 9987' Jewelry Detail • + +'! 10 ' '` of Top °10,115' LONG STRING Depth (RKB) Length ID Item 19.1er _ MO 55' 2.99 Cooper Dual Hanger 7' CBL _ 1 9,794' 26.97' 2.687" Trico Kobe Pump Cavity TOC - S.Sleeve, HES RA SSD # 10.150' =P.rf: 2 9,836' 3.56' 2.56" 121RA25623 10150'- 10713' S.Sleeve, HES RA SSD # , = 3 9,871' 3.55' 2.56" 121RA25623 4 9,890' 3.29' 2.56" HES "PRO" Safety valve Nipple 5 9,925' 10.11' 3.03" Locator Seal ASSY w /8.66' of seals 6 9,925' 6.04' 3.88" HES VTL Retrievable Pkr. Sr# - - 12VTL96038 -2 7 9,931' 7.40' 3.88" Seal Bore extension 8 9,938 .58' 2.99' XO 1 9 10,002' 1.47 2.56° Model "R" Profile Nipple 10 10,043' .80' 2.42° XO 3 Y :" BTC box x 2 Yo" 8rd pin 31.67' 2.441 1 jt 2 7/8° TBG cut @ 10,075' y ' TOF@ SHORTSTRING ,, 10,745' 55' 2.99" Cooper Dual Hanger A 9,785' .86' 1.995" XO, 3 W x 2 %" B 9,786' 10.09' 1.995' Tbg Pup jt C 9,794' 26.97 Trico Kobe Pump Cavity o 7 "@ � Perforations 11,703' Zone Top Btm Ft Accum.SPF Date Comments TD= 11,709' 76 088' PBTD = 111,,602' Hemlock 10,150' 10,158' 8' 4 5/10/2002 MAX HOLE ANGLE = 82 ° ©11,650'MD Hemlock 10,164' 10,170' 6' 4 5/10/2002 Hemlock 10,180' 10,200' 20' 4 5/10/2002 Hemlock 10,250' 10,280' 30' 4 5/10/2002 Hemlock 10,348' 10,368' 20' 4 5/10/2002 Hemlock 10,428' 10,440' 12' 4 5/10/2002 Hemlock 10,580' 10,610' 30' 4 5/10/2002 Hemlock 10,665' 10,695' 30' 4 5/10/2002 Hemlock 10,230' 10,718' 488' 4 7/18/1994 TCP Note: • Re- perforated all Hemlock intervals, 05/09/02 • Both Sliding Sleeves closed 4/21/2011 • Jug Test Passed w/plug in tubing at 10,002' - LS= 2950psi, SS= 2400psi, 9- 5/8 "= 2400psi • Temp -Press Survey completed 7/23/2011 to 9843', could not pass. WBD Di -16. doc AC 11 -2010 I • • Bundle (i.e. Jug) Test for Di -16 Completed on 6/20/2011. c. h v, a Zo . Zo i it"(* Cj.f • • • (Chevron 1 WeII:IDi -16 Long 1 Field: 'Dillon 107 -23 -2011 I Pressure (psia) 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 ' II Pressure- Temperature Profile i 500 � — 1. Going in hole to 9844' II 1000 I 1500 2000 2500 3000 3500 1 4000 d ,� 4500 _ , 5000 Q. 5500 _ CD 0 6000 6500 7000 7500 % 8000 8500 9000 I. Mk 9500 10000 1 1 I 1 1 1 1 1 1 1 I 1 50 60 70 80 90 100 110 120 130 140 150 160 170 180 Temperature (Deg. F) — Pressure —13 3/8" 7" LS Tbg —18 5/8" 9 5/8" — SS Tbg — Temperature Report date: 7/28/2011 Chevron • • Chevron - Alaska ONO Weekly Operations Report sr F,,, „:...,:..,. ., .. ., •.... Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) 01-16 S MGS UNIT 16 ADL0018746 5073320459 QU1379 110.00 Primary Job Type Job Category Objective Actual Start Date Actual End Date Mechanical Integrity Test Well Services 6/20/2011 Primary Wellbore Affected Wellbore UWI Well Permit Number DI -16 507332045900 1940570 0411k' OAertroii ? .. °.. . 6/20/2011 00:00 - 6/21/2011 00:00 Operations Summary Notified AOGCC Jim Regg 6/19/2011. R/U Slickline, pressure test lubricator to 250 psi low /3000 psi high. RIH w/2.5” GR to 10,034'. RIH w/ 2.5" R Xline Running tool and 2.56" PR plug body to 9,836', will not pass, POOH, redress. RIH w/ same to 10,002', set plug body. RID Slickline. Pump filtered Inlet water (FIW) down annulus to 2400 psi. Allow annulus, LS, and SS to stabilize. MIT Bundle Pressure Test passed. Starting pressures: Long string: 1000psi Short string: 300psi 9 5/8: 400psi 13 3/8: 15psi 18 5/8: 250psi Stabilized pressures: Long string: 2950psi Short string: 2400psi 9 5/8: 2400psi 13 3/8: 60psi 18 5/8: 250psi Chevron • Chevron - Alaska Weekly Operations Report Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) DI -16 S MGS UNIT 16 ADL0018746 5073320459 QU1379 110.00 Primary Job Type Job Category Objective Actual Start Date (Actual End Date Mechanical Integrity Test Well Services 6/20/2011 Primary Wellbore Affected Wellbore UWI Well Permit Number DI -16 507332045900 1940570 D0.KN44i1S 7/23/2011 00:00 - 7/24/2011 00:00 Operations Summary RIH w /tandem pressure temp gauges. RIH to 9843', could not pass, POOH. R/D E -line, secure well. -} • Page 1 of 3 Regg, James B (DOA) From: Brooks, Phoebe L (DOA) 14(.7%, 0 Sent: Tuesday, April 26, 2011 2:07 PM To: Quick, Mike [ASRC] P 14'05 Cc: Regg, James B (DOA); Maunder, Thomas E (DOA) /45 Subject: RE: Dillon platform MIT of Di -16 & di -17 Attachments: MIT MGS 16,17 04- 22- 11.xis Mike, Attached is a revised MIT report for MGS 16,17 04- 22 -11. The AOGCC Rep field is now blank (an inspector's name is entered only when witnessed); LS was removed from the Pretest tubing data as these fields are numeric (long string was added to the notes); "0" was entered in the interval field for 16; the AI0 # was included in each note field. Please let me know if you have any questions or disagree. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907- 276 -7542 From: Quick, Mike [ASRC] [mailto:MQuick ©chevron.com] Sent: Tuesday, April 26, 2011 11:07 AM To: Quick, Mike [ASRC]; Regg, James B (DOA); Maunder, Thomas E (DOA); Hauck, Shane R; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Hammons Jr, Darrell James; Neighbors, Joel [Swift Technical Services]; Kanyer, Christopher V; Bonnett, Nigel (Nigel.Bonnett) Subject: RE: Dillon platform MIT of Di -16 & di -17 Correction: The chart we used was a 24 hour chart (1 day), not a 7 day chart as stated below. We could not locate any 3 hour charts for our recorder in time for this pressure test. Apologies for the typo. Mike From: Quick, Mike [ASRC] Sent: Tuesday, April 26, 2011 10:49 AM To: 'Regg, James B (DOA)'; Maunder, Thomas E (DOA); Hauck, Shane R; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Hammons Jr, Darrell James; Neighbors, Joel [Swift Technical Services]; Kanyer, Christopher V; Bonnett, Nigel (Nigel.Bonnett) Subject: RE: Dillon platform MIT of Di -16 & di -17 Please find the attached updated MIT Report form including the test data from the long string on Di -17 (PTD 194 -056). This test was recorded on a 7 day chart for +/ -45 minutes of chart time, causing the line to appear to have not stabilized, but according to Mr. Hauck, 70 psi total was lost in 30 minutes, and the pressure had stabilized at the end of the test. Note additionally that the tubing pressure was constant throughout the 9- 4/26/2011 • Page 2 of 3 5/8" casing /packer test at 1,008 psi for 30 minutes. Also, the tubing still contains compressible reservoir fluids, as we are not equipped to circulate the well to water at this time. Please let me know if we can provide any additional information. Regards, Mike Mike Quick Project Manager / Drilling Engineer MidContinent /Alaska SBU Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, Alaska 99503 Direct 907 - 263 -7900 Fax 1 -866- 480 -5398 mquick@chevron.com From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, April 25, 2011 4:39 PM To: Quick, Mike [ASRC]; Maunder, Thomas E (DOA); Hauck, Shane R; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Hammons Jr, Darrell James; Neighbors, Joel [Swift Technical Services]; Kanyer, Christopher V; Bonnett, Nigel (Nigel.Bonnett) Subject: RE: Dillon platform MIT of Di -16 & di -17 Di -17 (PTD 1940560) original message includes test charts of MITs on 9 -5/8 by tubing (MITIA) and on Tubing longstring (MITT) MITIA test clearly is a pass but MITT is questionable - do not see from chart recording where pressure drop stabilized Also, both tests need to be reported on the MIT Report Form Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Quick, Mike [ASRC] [mailto:MQuick @chevron.com] Sent: Monday, April 25, 2011 12:46 PM To: Maunder, Thomas E (DOA); Hauck, Shane R; Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Hammons Jr, Darrell James; Neighbors, Joel [Swift Technical Services]; Kanyer, Christopher V; Bonnett, Nigel (Nigel.Bonnett) Subject: RE: Dillon platform MIT of Di -16 & di -17 Mr. Maunder — Both wells had a small gas cap on them, so Shane bled gas on each well. We pumped filtered inlet water for the pressure tests. On Di -16, after running an isolation sleeve in the Kobe cavity with a solid bottom, and bleeding the 9 -5/8" casing pressure 4/26/2011 • Page 3 of 3 down to zero, we pumped approximately 5 bbls of FIW in 54 minutes, pressuring the 9 -5/ casing by tubing b tubin annulus to 2300 psi. The pressure bled off 125 psi in 7 minutes. A second pressure test was attempted 1.5 hours later, pumping an additional +/- 5 bbls of FIW and pressuring the 9 -5/8" casing by tubing annulus to 2300 psi. The pressure bled off 150 psi in 10 minutes. A third pressure test was attempted 1.25 hours later, pumping an additional +/- 5 bbls of FIW and pressuring the 9 -5/8" casing by tubing annulus to 2300 psi. The pressure bled off 150 psi in 10 minutes. Shut down for night. A fourth pressure test was attempted the next day, pumping an additional +/- 4 bbis of FIW and pressuring the 9 -5/8" casing by tubing annulus to 2400 psi. The pressure bled off 150 psi in 10 minutes to 2250. Both the sliding sleeves on Di -16 had been open for some length of time prior to being closed this week, and it is possible that they are leaking, as they are located below the Kobe cavity and above the 9 -5/8" packer. In all tests, the tubing pressures increased slightly due to compression (LS +1- 900 to 1000 psi, SS +/- 350 to 400 psi), but are not in communication with the annulus above the Kobe cavity isolation sleeve. Please let me know if you have any further questions. Regards, Mike From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, April 25, 2011 7:09 AM To: Hauck, Shane R; Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Quick, Mike [ASRC]; Hammons Jr, Darrell James; Neighbors, Joel [Swift Technical Services] Subject: RE: Dillon platform MIT of Di -16 & di -17 Hi Shane, On Di -16, how would you describe the pumping operation you attempted? How much and what did you pump and was there any pressure response on the well? Thanks in advance, Tom Maunder, PE AOGCC From: Hauck, Shane R [mailto:haucks @chevron.com] Sent: Sunday, April 24, 2011 9:39 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA) Cc: Quick, Mike [ASRC]; Hammons Jr, Darrell James; Neighbors, Joel [Swift Technical Services] Subject: Dillon platform MIT of Di -16 & di -17 Jim Here is our M.I.T paper work Di -17 was good But Di -16 failed Thanks Shane R Hauck Drill Site Manager Midcontinent/Alaska SBU Chevron North America Exploration and Production Office 907 - 263 -7613 Fax 1- 866 -914 -1485 Cell 907 - 250 -2713 Rig 907 - 776 -6639 haucks @chevron.com 4/26/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regaCci7alaska.gov; doa. aogcc.prudhoe.bay(rDalaska.gov; phoebe.brooks(nDalaska.gov; tom.maunder/ alaska.gov OPERATOR: Union Oil Company of California FIELD 1 UNIT I PAD: Middle Ground Shoal Field / E F and G oil pool DATE: 04/22/11 OPERATOR REP: Shane R Hauck AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Di -17 Type Inj. I TVD ' 8,922' Tubing 1,090 1,008 1,008 1,008 Interval 0 P.T.D. 1940560 Type test P Test psi - 2230.5 Casing 780 2,345 2,345 2,345 ' P/F P ' Notes: AIO 8.005 authorizes injection; MITIA OA 38 55 55 55 Prepare Di -17 well for disposal of fluids from decommissioning operations on platform; longstring tubing Well Di -16 ' Type Inj. I TVD - 9,292' Tubing 1,240 Interval 0 P.T.D. 1940570 ' Type test P Test psi ' 2323 Casing 525 P/F F Notes: AIO 8.005 authorizes injection OA 10 Unable to get Pre- test on 9 -5/8" X tbg (did not attempt MIT test); longstring tubing Well Di -17 - Type Inj. I TVD 8,922' Tubing 990 2,600 2,550 2,530 Interval 0 P.T.D. 1940560 Type test P Test psi_ 2230.5 Casing 1,550 1,550 1,550 1,550 P/F P Notes: AIO 8.005 authorizes injection; MITT OA 38 38 38 38 longstring tubing Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test_ Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test dunng Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT MGS 1617 04 0 • MIT — S. Middle Ground Shoal Unit 17 Dillon Platform PTD 1940560 4/22/2011 , . MITIA v — z: — r D.U.a Di - M r 1S9► rt44 S1u.� y ... N,we K 1 ;O Jw 1 "1 t 6.04 f$ _.... , . Fri , ,, a • - „.r ; 0.-- , y-LL-if '' M1 -' At MITT i 7A a .s � `` �.� 3r1 ~-,. Al ' S' aS3d , t �t .i'k1/4 _ : 1 C • • Chevron Timothy C Brandenburg Union Oil Company of California 1%10 Drilling Manager P.O. Box 196427 Anchorage, AK 99519 -6247 Tel 907 263 7657 Fax 907 263 78888 4 Email brandenburgt @chevron.com March 8, 2011 RECEIVE." Commissioner MAR 0 8 Alaska Oil & Gas Conservation Commission Alaska Oil & O� Cons, Commission 333 W. 7 Avenue Anchorage, Alaska 99501 ,moorage Re: Dillon Platform: Area Injection Order Administrative Approval 8.2 and 8.3 Dear Commissioner, Union Oil Company of California (UOCC) respectfully requests that Area Injection Order 8.2 (AIO 8.2) dated January 29, 2003, and AIO 8.3 dated March 4, 2003, be amended to include two wells on the Dillon Platform, S MGS Unit 17 (Di -17) PTD 194 -056 and S MGS Unit 16 (Di- 16) PTD 194 -057. These two wells, Di -17 and Di -16, were oil producers when the platform halted production in 2003, and under separate cover 10 -403 forms have been submitted to change their status to EOR (enhanced recovery) water injector. The currently approved EOR wells, Di -12 (PTD 168 -056) and Di -14 (PTD 175 -066), authorized for waste injection per AIO 8.2 and 8.3 on the Dillon Platform, are in questionable service state per the October 2009 work on the platform. UOCC plans to circulate out 15 wells on the Dillon Platform commencing in June 2011, in advance of planned well abandonment activity. By UOCC records, a total of 6,347 barrels of Class II waste j liquid have been injected into Di -12, and a total of 1,613 barrels of Class II waste q liquid have been injected into Di-14, for a total of 7,960 barrels out of the authorized 50,000 q injected leaving 42,040 barrels of authorized disposal volume remaining per AIO 8.2. At this time, UOCC estimates that the injection requirements for circulation and abandonment Class 11 fluid disposal will be under the remaining limit of 42,040 barrels. Per AIO 8.0, 8.2 and 8.3, this Class 11 injection liquid will primarily consist of filtered and unfiltered inlet water, kill weight brine or mud, produced water, produced oil, cementing waste fluids (cement pushes, surfactants, rinsate), water with some detergents used to clean equipment, and deck drainage due to rainfall on the platform. UOCC will not dispose of solids (no grind and inject operation) or domestic sanitary waste into these wells. Please let us know if we can provide any further information by contacting myself at 263 -7657 or Mike Quick at 263 -7900. Sincerely, te Timo C. Brandenbur•4# Drilling Manager Union Oil Company of California / A Chevron Company • • Page 1 of 2 Maunder, Thomas E (DOA) From: Quick, Mike [ASRC] [MQuick @chevron.com] Sent: Thursday, March 10, 2011 2:57 PM To: Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Kanyer, Christopher V Subject: RE: Request on Dillon Wells Tom — am having a copy of each log made for your files, and should have them to you by the middle of next week. Thanks, Mike From: Maunder, Thomas E (DOA) [mailto:tom.maunder©alaska.gov] Sent: Thursday, March 10, 2011 2:12 PM To: Quick, Mike [ASRC] Cc: Greenstein, Larry P; Kanyer, Christopher V Subject: RE: Request on Dillon Wells Thanks Mike. As I am reviewing the files, I find that cement evaluation logs were run in both wells however I have not been able to locate any copies over here. Does Unocal /Chevron have copies of the cement logs available? Tom From: Quick, Mike [ASRC] [mailto:MQuick @chevron.com] Sent: Thursday, March 10, 2011 11:34 AM To: Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Kanyer, Christopher V Subject: RE: Request on Dillon Wells Mr. Maunder — Thank you for the follow up questions on our request for Administrative Approval for Dillon wells 16 and 17. We have submitted 10 -403 forms for each well to change their status, and have outlined how we plan to perform an MIT within that request. Here is what we submitted along with the 403's in regard to your question: Mechanical integrity of each well will be demonstrated with a pressure test under 20 AAC 25.412. Di -17: Install standing valve in long string tubing and perform bundle test to 2231 psi (packer depth of 9177' MD / 8922' TVD) to verify integrity of packer and 9 -5/8" casing. Install dummy pump in Kobe cavity and perform a Standard MIT on the tubing long string to 2231 psi to verify integrity of tubing long string (pressure will be kept on 9 -5/8" casing and will be monitored during test, tubing short string will be isolated with the dummy pump and will be monitored during test). Di -16: Install standing valve in long string tubing and perform bundle test to 2323 psi (packer depth of 9925' MD / 9292' TVD) to verify integrity of packer and 9 -5/8" casing. Install dummy pump in Kobe cavity and perform a Standard MIT on the tubing long string to 2323 psi to verify integrity of tubing long string (pressure will be kept on 9 -5/8" casing and will be monitored during test, tubing short string will be isolated with the dummy pump and will be monitored during test). 3/15/2011 • • Page 2 of 2 In regards to your question on information regarding MIT and pump in, a MIT test was successfully performed on Di -17 in December 2002 (the short string was isolated for the test, as it has communication with the 9 -5/8" annulus). Neither well has any pump in history. Please let me know if I can provide any further details or information. Best Regards, Mike Mike Quick Project Manager / Drilling Engineer MidContinent /Alaska SBU Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, Alaska 99503 Direct 907 -263 -7900 Fax 1- 866 - 480 -5398 mquick(a�chevron.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, March 10, 2011 10:53 AM To: Quick, Mike [ASRC] Cc: Greenstein, Larry P Subject: Request on Dillon Wells Mike and Larry, I am looking at the request regarding waste injection into SMGS 16 and 17. I have looked at the files as well as the LTSI information that Larry sends monthly. From examination of the LTSI plots, it appears that 16 has "better" isolation than 17. At least the casing pressures appear to be more stable on 16 than 17. What plans might you have for performing an MIT or a pump in on the wells? Do you already have any information regarding MIT and pump in? Thanks in advance for your reply. Tom Maunder, PE AOGCC 3/15/2011 UNOCAL V6 Dillo latform • Welli -17 API# 50- 733 - 20458 -00 CT RRENT CON1PLETION Completed 6 /15/95 RKB to Tbg Hngr = 54.12' 1 C a s i n g & T u b i n g ' 1 Si ze Wt Grade Thread ID Top Btm 32" Surface 83' 18 -5/8" 97.7# X -56 QTE60 17.653 Surface 1133' 13 -3/8" 68# K -55 BTC 12.415 Surface 3548' 9 -5/8" 47# L -80 BTC 8.681 Surface 9484' Liner 7" 1 324 1 P -lI0 1 TKC -BTC 1 6.094 1 9314' 1 11472 Tubing 3 -112" 9.2# L -80 SCBTC 2.992 Surf 9038 3 -1/2" 9.2# L -80 SCBTC 2.992 Surf 9038 Jewelry Item Depth Length 1 ID 1 Description LONG STRING 55.42' 2.99 Cooper Dual Hanger 1. 9038' 26.30' 2.687 Trico Kobe Pump Cavity 2. 9081' 3.54 2.56 S lidijg Sleeve, HES RA SSD # 12IRA25623 3. 9116' 3.54' 2.56 Sliding Sleeve, HES RA SSD # 121 RA25623 4. 9136' 8.75' 2.56 Baker FV6E TRSV 1 ,y, B 5. 9177' 11.47' 2.99 Locator Seal Assy w/ 10.45' of seals. C 6. 9177' 6.79' 5.00 HES VST Retrievable Pkr. Serial # I2VST96350 -2 .. 7. 9184' 7.40' 5.00 Seal Bore Extension 8. 9191' .68' 2.99 Crossover 2 — , 9. 9208' 1.44' 2.56 Model "R" Profile Nipple 3 10. 9215' _ .45' 3.45 WLEG -al 4 SHORT STRING 5 55.42' 2.99 Cooper Dual Hanger I 17 A. 9029' 1.08' 1.995 Crossover, 3 -1/2" x 2 -3/8" 8 III B. 2930' 10.05' 1.995 Tbg Pup Jt. lie 9 C. 9040' 26.30' Trico Kobe Pump Cavity 10 N. m. G - 3 Perforations Zone Top 9,876' Btm Ft SPF Date Comments WC @ ' G 03 9,900' 24' 10,270' G -03 9,918' 9,946' 28' G -03 9,956' 10,045' 89' G -03 10,054' 10,232' 178' G 03 10,432' 10,889' 457' 1 G -03 10,897' 11,018' 121' • G -02 11,132' 11,231' 99' • G -2 G -02 11,260' 11,279' 19' G -01 11,376' 11,400' 24' G - CD = 11,472' PBTD = 11,419' VIax Deviation = 83.09° @ 11,260' Plot lessure & Rate vs Time - Well Di -17 • 1200 - 1000 - 800 1,,..........................................................,........ '••••9 5/8" y 13 3/8" r2 Tubing 600 - - - - - -. - ' -- - - -- - ... -- - - -' - -- -- - -- ---- ._.. -._ y - -- li — Tubing 2 400 — — — 200 . 0 `-. 1 Rj/ �—' c0 co co 00 W 0) 0) O) m CO O) O) O) O) O) O) O) 0 0 0 0 0 0 0 0 0 0 0 0 o o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o CD o, 0 w 1- a w izz: r - 0 a a a v 0) M (V n) a a a o) - a 36 n 3)- 3) N N N N (\l N (V N N N N N N N N N N lV (\ N N N N N Z3 O) O N N 1') 8 N (O 1- a0 O) a N N M V (n (O r 00 O) O N N O O 0) O O O O O O O O •- O O O O O O O O O O c c - 7 ; j 13 3/8" - 284 TIO Report 02/15/11 0 20 1100 01/05/11 0 20 1090 Data Sheet 12/14/10 0 10 1090 11/17/10 0 20 1090 10/29/10 0 20 1080 108 Di -17 10/09/10 0 20 - 08/11/10 750 0 20 1080 1080 07/14/10 750 0 20 1080 1075 BOT HOLE HYD PUMP 06/16/10 740 0 20 1070 1070 05/19/10 730 0 20 1070 1060 04/21/10 730 0 20 1070 1060 Permit # 1940560 03/24/10 730 0 20 1070 1060 02/17/10 720 0 20 1060 1060 01/20/10 710 0 20 1060 1050 API # 50- 733 - 20458 -00 12/20/09 700 0 20 1050 1050 11/25/09 700 0 20 1060 1050 10/31/09 700 0 20 1050 1050 08/30/2008 to 03/01/2011 10/30/09 700 0 20 1050 1060 10/29/09 700 0 20 1050 1060 10/28/09 700 0 20 1050 1060 10/27/09 700 0 20 1050 1060 10/26/09 700 0 20 1050 1060 10/25/09 700 0 20 1060 1050 10/24/09 710 0 20 1050 1050 10/23/09 660 0 20 1000 1000 10/16/09 900 30 20 1050 1050 10/10/09 900 20 20 1050 1050 10/02/09 890 20 20 1050 1050 09/25/09 880 20 20 1050 1050 09/12/09 890 20 20 1050 1050 09/10/09 880 20 20 1050 1040 09/09/09 880 20 20 1050 1040 09/08/09 880 20 20 1050 1050 08/29/09 880 20 0 1050 1050 08/28/09 880 20 0 1050 1050 08/27/09 880 20 20 1050 1040 3/10/2011 8:44 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 03 01 (6).xls Di -17 Plot Pressure & Rate vs Time - Well Di -17 • 1200 1000 800 - - — — '''''9 5/8" I a) 13 3/8" 1 6 v i 600 20' -- -- - - - - -- - -- --- - -- - - -- - _ - - - -- - --- - - - - -- -- - -- Tubing a — Tubing 2 400 200 . r� t1 0 -- .0 co co co oo co co ao co co co co 0 07 07 0 o 0 o) 0 O o 07 0, o o O O o 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o o) o o) co w o r O (0 o o v (0 in o v (h o A 0 0 0) ao 0 0) 0 w m (CO N on N N (V N N N N N N N N N N (V (V N N N N N (V .- N .- (V (0 V (() (O ^c- W o) O (V N (h O (() (D r ao m O (V g N (0 -8 (() (O r o O O o O O O O O 0 O O O O O O O - O O O O O O O Date 13 318" 20" WPM 2 TIO Report 07/14/10 0 20 1080 1075 06/16/10 0 20 1070 1070 Data Sheet 05/19/10 0 20 1070 11s 04/21/10 0 20 1070 1iO( 03/24/10 0 20 1070 10.1' Di -17 02/17/10 0 20( iiifia mina 01/20/10 710 0 20 1060 1050 12/20/09 700 0 20 1050 1050 BOT HOLE HYD PUMP 11/25/09 700 0 20 1060 1050 10/31/09 700 0 20 1050 1050 10/30/09 700 0 20 1050 1060 Permit # 1940560 10/29/09 700 0 20 1050 1060 10/28/09 700 0 20 1050 1060 10/27/09 700 0 20 1050 1060 API # 50- 733 - 20458 -00 10/26/09 700 0 20 1050 1060 10/25/09 700 0 20 1060 1050 10/24/09 710 0 20 1050 1050 01/30/2008 to 07/31 /2010 10/23/09 660 0 20 1000 1000 10/16/09 900 30 20 1050 1050 10/10/09 900 20 20 1050 1050 10/02/09 890 20 20 1050 1050 09/25/09 880 20 20 1050 1050 09/12/09 890 20 20 1050 1050 09/10/09 880 20 20 1050 1040 09/09/09 880 20 20 1050 1040 09/08/09 880 20 20 1050 1050 08/29/09 880 20 0 1050 1050 08/28/09 880 20 0 1050 1050 08/27/09 880 20 20 1050 1040 08/26/09 880 20 20 1040 1040 08/25/09 880 20 20 1040 1040 08/24/09 880 20 20 1050 1050 08/23/09 880 20 20 1040 1040 08/22/09 880 20 0 1040 1040 08/20/09 880 20 20 1040 1050 08/17/09 880 20 20 1040 1040 3/10/2011 9:32 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2010 07 31 (5).xls Di - 17 • • Plot Pressure & Rate vs Time - Well Di -17 1200 _- .._... - -. , —9 5/8" 13 3/8" Tubing 1000 1 — Tubing 21 800: A ' k ib b. ._... Wi.n..-- ---"411111 d r_ 7 N 600 N i a 400 - - - - 200 Lc) co co ro <o n n n r• 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Date 13 3/8" ' 20" • TIO Report 01/23/08 0 20 940 12/19/07 0 40 920 Data Sheet 11/21/07 0 - 10/17/07 800 0 20 910 940 09/12/07 770 0 20 900 920 Di -17 08/12/07 760 50 40 900 980 07/18/07 760 50 20 890 970 06/13/07 750 50 20 880 960 BOT HOLE HYD PUMP 05/16/07 740 50 20 870 960 04/18/07 730 50 40 860 950 03/22/07 730 50 20 860 940 Permit # 1940560 02/21/07 720 50 20 870 920 01/18/07 720 50 20 840 910 12/15/06 710 60 40 830 900 API # 50- 733 - 20458 -00 10/20/06 700 60 30 810 880 09/29/06 690 60 30 800 880 09/04/06 670 70 50 800 870 11/01/2005 to 01/31/2008 07/20/06 680 70 30 780 860 06/25/06 660 60 40 750 800 05/24/06 660 70 0 950 850 04/21/06 650 80 30 760 750 03/17/06 640 90 30 740 730 02/26/06 640 80 0 740 720 01/19/06 630 110 60 720 720 12/08/05 660 400 50 800 700 11/18/05 600 380 60 125 710 11/01/05 3/10/2011 9:28 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2008 01 31.xis Di -17 • • Plot Pressure & Rate vs Time - Well Di -17 1200 - ■ 1000 800. Tubing — Tubing 2 11666' 9 5 /8" 13 3/8" N 600 20 ' di ""��. •, T � 11,1 T A 7 400 • -' 8 --- 200 1 0 f - - �""T— o v 0 0 o 0 0 0 0 0 0 2Z m r h N N M r u . Time DATE HRS ON Tubin• Tubin• 2 9 5/8" 13 3/8" 20" 01/19/06 0 '00 ' ' 0 630 110 60 Wavered Well 12/08/05 0 800 701 660 400 50 11/18/05 0 "r. 710 600 380 60 Data Sheet 10/24/05 0 740 680 610 390 70 10/18/05 0 125 710 600 380 60 09/20/05 0 710 660 560 0 0 Di -17 08/20/05 0 640 6 580 40 40 07/21/05 0 400 520 0 10 07/02/05 0 700 44 600 110 25 Permit # 1940560 05/21/05 0 375 400 590 0 20 04/16/05 0 250 350 560 5 25 02/24/05 0 500 320 10 21.5 30 API # 50- 733 - 20458 -00 01/29/05 0 625 340 550 38 36 12/28/04 0 600 360 540 38 38 11/13/04 0 600 450 490 38 38 02/01/2004 to 01/31/2006 10/31/04 0 600 450 490 38 38 10/06/04 0 09/30/04 0 580 420 510 40 40 08/20/04 0 525 450 490 40 40 07/07/04 0 490 460 480 38 40 06/23/04 0 500 180 470 38 40 04/30/04 0 450 280 440 35 38 03/24/04 0 400 150 410 34 38 01/27/04 0 250 130 400 38 0 12/26/03 0 250 110 350 35 40 12/15/03 0 250 110 350 35 40 11/04/03 0L 0 320 32 38 3/10/2011 9:24 AM - Wavered Wells Reports v7b.xls J J Dolan Wavered Well Report Jan 2006.xls Di -17 Mid a Ground Shoal Field UNOCAL.) • Di11Platform Well Di -16 API# 50- 733 - 20459 -00 CURRENT COMPLETION' Completed 7/20/94 Casing & Tubing RKB to Tbg Hngr = 55' I Size Wt Grade Thread ID Top Btm 30" Surface 83' � , I 18 -5/8" 97.74 X -56 QTE60 17.653 Surface 1132' 13 -3/8" 684 K -55 BTC 12.415 Surface 3640' II 9-5/8" 47# L -80 BTC 8.681 Surface 10,155" Liner 7" 1 32# 1 P -110 1 TKC -BTC 1 6.094 1 9988' 1 11,703' Tubing LS 3 -1/2" 92# L -80 SCBTC 2.992 Surf 9794' SS 3 -I /2" 924 L -80 SCBTC 2992 Surf 9796' t Jewelry Item I Depth Length I ID I Description LONG STRING 55' 299 Cooper 13 -5/8" 5k Dual Hanger 1. 9794' 2697' 2.687 Trico Kobe Pump Cavity 2, 9836' 3.56' 2.56 Sliding Sleeve, HES RA SSD # 121RA25623 3. 9871' 3.55' 2.56 Sliding Sleeve, HES RA SSD # 121RA25623 4. 9890' 3.29' 2.56 HES Model "RRO" Safety Valve Nipple 5. 9925' 10.11' 3.03 Straight Slot Locator Seal Assy w/ 8.66' of seals. 6. 9925' 6.04' 3.88 HES VTL Retrievable Pkr. Serial # 12VTL96038 -2 { s A 7. 9931' 7.40' 3.88 Seal Bore Extension B 8. 9938' .58' 2.99 Crossover 1 9. 10,002' 1.47' 2.56 Model "R" Profile Nipple C 10. 10,043' .80' 2.42 Crossover 3-1/2" BTC box X 2 -7/8" 8rd Pin . • 31.67' 2.441 1 Joint of 2 -7/8" Tubing. Cut (r, 10,075' 2 G U N F I S H Total Length of fish=648' 3 11. 10,743' 1.67' 2.25 Mechanical Tubing Release 4 94.80 2.441 3 Joints of 2 -7/8 ", 6.4#, L -80, EUE 8rd Tubing 5 2. .42 1.995 Crossover, 2 -7/8" EUE 8rd x 2 -3/8" 1 ! I 4.07 1.995 2 -3/8" Pup Joint 8 V 1.38 1.79 Otis "XN" Nipple 9.89 1.995 2 -3/8" Pup Joint 9 .33 1.995 Crossover, 2 -3/8" x 2 -7/8" EUE 8rd . 10 2.24 2.441 2 -7/8" Balanced Isolation Production Sub .42 1.995 Crossover, 2 -7/8" EUE 8rd x 2 -3/8" 30.12 1.995 3- 2 -3/8 x 10' Pup Joints 5.51 1.57 Mechanical Firing head 4.15 - 4 -5/8" Gun Blank TUC @ 488.00 - 4 -5/8 ", 4 spf TCP Gun 10,210' IF - 41 1.54 4 -5/8" Gun Blank 1.10 EDA Ml 2.39 - Time Delay Firing Head Hemlock Btm of Fish @ 11,391' SHORT STRING tl 55' 2.99 Cooper 13 -5/8" 5k Dual Hanger ''' 11 A. 9785' .86' 1.995 Crossover, 3-1/2" x 2 -3/8" r B. 9786' 10.09' 1.995 Tbg Pup Jt. �' C. 9796' 26.97' - Trico Kobe Pump Cavity I Perforations Accum %` of Zone Top Btm Ft SPF Date Comments ,g- Hemlock 10,150' 10,158' 8' 4 5/1.012002 lc Hemlock 10,164' 10,170' 6' 4 5/10/2002 �rf Hemlock 10,180' 10,200' 20' 4 5/10/2002 i Hemlock 10,250' 10,280' 30' 4 5/10/2002 il Hemlock 10,348' 10,368' 20' 4 5/10/2002 TD = 11,709' PBTD = 11,602' Hemlock 10,428' 10,440' 12' 4 5/10/2002 Hemlock 10,580' 10,610' 30' 4 5/10/2002 Max Deviation = 82° @ 11,650' Hemlock 10,665' 10,695' 30' 4 5/10/2002 10,230' 10,718' 488' 4 7/18/1994 TCP Dillon 16 dwg 7 -20 -94 Revised 5/20/02 SLT Plot *sure & Rate vs Time - Well Di -16 • 1400 1200 - -- - - `— 1000 —9 5/8" 13 3/8" 800 — — �r 20 26 — — z — Tubing w Tubing . 1 a 600 co 400 ... — — — — — 200 — — — - -- - -- — 0 CO CO CO CO CO 0 O) O) O) O) 0) CO 0 0) 0 0) O) 0 0 0 0 0 0 0 0 0 0 0 0 1 1 o o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o a) a, co co r co CO r- r co co co V a M C) N C) N N 0 O) O) ao CO N- CO M N N N N N N N N N CV N N CV N N N N N N (V N N N N ,- 7 7 8 8 O N N 0)) Q )O CO 0 CO O) O N N 2 a N CO 6- a O o 0 N 0 N o 0 0 0 0 0 0 CC 0 0 0 '- 0 0 0 0 0 C) 0 0 o •- 0 0 Date 13 3/8" ` 20" 26" rpsogromign TIO Report 02/15/11 25 180 200 390 1270 01/05/11 30 200 240 390 1280 Data Sheet 12/14/10 30 200 240 400 1270 11/17/10 30 200 240 390 127a 10/29/10 35 210 240 400 Di -16 10/09/10 40, 200 240�� 08/11/10 540 40 220 1250 380 07/14/10 540 40 220 240 1250 380 BOT HOLE HYD PUMP 06/16/10 530 40 200 220 1240 380 05/19/10 530 40 250 180 1240 370 04/21/10 530 40 70 100 1230 370 Permit # 1940570 03/24/10 530 40 60 100 1220 370 02/17/10 520 40 60 1210 360 01/20/10 520 50 60 90 1200 360 API # 50- 733 - 20459 -00 12/20/09 520 50 70 100 1200 360 11/25/09 520 60 60 100 1200 360 10/31/09 520 70 80 100 1190 350 08/30/2008 to 03/01/2011 10/30/09 520 75 80 1195 360 10/29/09 520 75 80 1195 360 10/28/09 520 75 80 1195 360 10/27/09 520 75 80 1190 360 10/26/09 520 70 80 1190 360 10/25/09 520 75 80 100 1190 360 10/24/09 510 0 90 1180 380 10/23/09 510 0 90 100 1180 380 10/22/09 510 0 90 100 1180 380 10/21/09 500 0 100 100 1180 370 10/16/09 560 0 100 120 1240 400 10/10/09 560 0 100 110 1230 380 10/02/09 560 0 100 120 1160 400 09/25/09 560 20 100 120 880 400 09/12/09 560 0 100 120 920 390 09/10/09 560 0 100 120 980 390 09/09/09 560 0 100 140 940 400 09/08/09 560 0 100 140 920 380 08/29/09 560 0 120 140 980 380 3/10/2011 8:44 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 03 01 (6).xls Di -16 Plot Pressure & Rate vs Time - Well Di -16 • 1400 r,..... 9 5/8" 13 3/8" 1200 -- 26 -------- - - - - -- - -- _ - -- — -- - - - -- -- - Tubing — Tubing 2 1000 -- 800 - - - - -- — —. ._ a) 3 N N a` 600 — — -- ■ 1 400 200 .._ - - - - ` _ m co co co co co m co co co co m 0) 0) 0) 0) a) 0) 0 0) a> 0) 0) 0) o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O o 0 0 0 0 0 F, z o O) O) O 00 00 t a t0 a a O C ') U) t') C) a a a 0 a0 o a O) a a0 C') N <'`: N N N N N N N N N N N N N ‘' N N N N N N N N a c7 V U) CO c0 0 O N N V U) CO n no 0) O N a (0 Q U) U) O O O O O O O O O •- '- '- O O O O O O O O O '- O O O O O O O Date 13 3/8" ; 20" 26" r g Tubing 2 TIO Report 07/14/10 40 220 240 1250 380 06/16/10 40 200 220 1240 380 Data Sheet 05/19/10 40 250 180 1240 370 04/21/10 40 - °' 70 100 1230 370 03/24/10 40 60 100 1220 370 Di -16 02/17/10 40 60 • /1,3 .,. 01/20/10 520 50 60 90 1200 360 12/20/09 520 50 70 100 1200 360 BOT HOLE HYD PUMP 11/25/09 520 60 60 100 1200 360 10/31/09 520 70 80 100 1190 350 10/30/09 520 75 80 1195 360 Permit # 1940570 10/29/09 520 75 80 1195 360 10/28/09 520 75 80 1195 360 10/27/09 520 75 80 1190 360 API # 50- 733 - 20459 -00 10/26/09 520 70 80 1190 360 10/25/09 520 75 80 100 1190 360 10/24/09 510 0 90 1180 380 01/30/2008 to 07/31/2010 10/23/09 510 0 90 100 1180 380 10/22/09 510 0 90 100 1180 380 10/21/09 500 0 100 100 1180 370 10/16/09 560 0 100 120 1240 400 10/10/09 560 0 100 110 1230 380 10/02/09 560 0 100 120 1160 400 09/25/09 560 20 100 120 880 400 09/12/09 560 0 100 120 920 390 09/10/09 560 0 100 120 980 390 09/09/09 560 0 100 140 940 400 09/08/09 560 0 100 140 920 380 08/29/09 560 0 120 140 980 380 08/28/09 560 0 120 140 940 380 08/27/09 560 0 120 140 940 380 08/26/09 540 0 120 140 980 380 08/25/09 540 0 120 140 980 380 08/24/09 560 0 120 140 920 380 08/23/09 560 0 120 140 940 380 08/22/09 560 0 120 140 960 380 3/10/2011 9:32 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2010 07 31 (5).xls Di -16 • • Plot Pressure & Rate vs Time - Well Di -16 1400 - 1200 ■-'9 5/8" 1000 13 3/8" — 20" 26" Tubing 800 1-7— Tubing 2 a> z N N a1 a 600 400 A ic..._... ,.., N/■•••••• • 200 - 0 - 0 0 0 0 0 0 0 0 0 0 Or 0 O O 0 O N N W N a a0 O O 0 O O O Date 13 3/8" '2c 26" i TIO Report 01/23/08 0 . 1 260 960 320 12/19/07 0 '!G 940 320 Data Sheet 11/21/07 0 • !0 250 iIIIIIMS011110 10/17/07 480 0 250 260 920 320 09/12/07 480 0 260 260 900 310 Di -16 08/12/07 470 0 260 260 970 300 07/18/07 470 0 250 260 960 300 06/13/07 460 0 250 260 940 300 BOT HOLE HYD PUMP 05/16/07 460 0 230 240 940 290 04/18/07 450 0 220 230 920 280 03/22/07 440 0 280 300 910 280 Permit # 1940570 02/21/07 440 0 240 240 890 270 01/18/07 440 0 280 300 890 270 12/15/06 430 0 240 250 870 260 API # 50- 733 - 20459 -00 10/20/06 420 0 260 830 250 09/29/06 420 0 260 280 820 250 09/04/06 400 0 290 820 240 11/01/2005 to 01/31/2008 07/20/06 400 0 270 810 240 06/25/06 320 0 240 250 880 210 05/24/06 390 0 250 870 220 04/21/06 390 0 240 240 860 220 03/17/06 380 0 250 840 210 02/26/06 370 0 220 840 210 01/19/06 370 0 300 300 820 200 12/08/05 400 0 200 200 820 230 11/18/05 330 0 170 180 810 11/01/05 3/10/2011 9:28 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2008 01 31.xIs Di -16 • • Plot Pressure & Rate vs Time - Well Di -16 1400 - 1200 — Tubing — Tubing 2 9 5/8" 13 3/8" 1000 20" — 26" 800 — — f'"'""" E 600 400 r• ......................----....—.....--.–--- ,,,,), . 200 - -- -- 7__- Y u, o 0 0 0 0 0 0 0 0 A r N M in N Time " ' m DATE HRS ON Tubin. Tubin. 2 9 5/8" 13 3/8" 20" 26" 01/19/06 0 020 240 370 0 300 300 Wavered Well 12/08/05 0 820 2s0 400 0 200 200 11/18/05 0 180 810 330 0 170 Data Sheet 10/24/05 0 180 ,800 360 0 295 10/18/05 0 180 ,810 330 0 170 09/20/05 0 0 7 00 0 0 0 0 Di -16 08/20/05 0 17b 71,0 340 0 275 07/21/05 0 720 ' 0 240 0 240 07/02/05 0 180 7 1, 340 0 260 Permit # 1940570 05/21/05 0 180 73/ 320 0 250 04/16/05 0 11 i 701 305 0 240 02/24/05 0 '140 681 300 0 240 API # 50- 733 - 20459 -00 01/29/05 0 120 660 300 0 250 12/28/04 0 .120 640 285 0 250 11/13/04 0 115 600 240 0 275 02/01/2004 to 01/31/2006 10/31/04 0 .: '115 600 240 0 275 10/06/04 0 09/30/04 0 110 600 260 0 270 08/20/04 0 100 540 245 0 280 07/07/04 0 90 530 230 0 280 06/23/04 0 90 520 220 0 280 04/30/04 0 90 480 200 0 250 03/24/04 0 60 450 190 0 260 01/27/04 0 595 0 150 0 70 12/26/03 0 50 380 160 5 70 12/15/03 0. 50 380 160 5 70 11/04/03 0L 50 150 0 105 3/10/2011 9:24 AM - Wavered Wells Reports v7b.xls J J Dolan Wavered Well Report Jan 2006.xls Di -16 4 20 Dillon D -14 (S MGS Unit 14 1750660) Compliance Reporting ffdmin Appro... Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Monday, November 23, 2009 1:57 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Aubert, Winton G (DOA) Cc: Nash, R Scott; Newell, Jack R [FEP]; Quick, Mike [ASRC]; KRAMER, TED E; Ross, Gary D Subject: Dillon D -14 (S MGS Unit 14 PTD 1750660) Compliance Reporting for Admin Approval AIO 8.004 Attachments: Di -14 Post Injection Report 11- 23- 09.pdf A .J To all, The Dillon disposal operations have been completed and the Di -14 is now shut -in again. This e-mail will provide the documentation of the adherence to the conditions of approval for the AA on the Di -14 well. The attached pdf contains the following: Pg 1 -2) Copy of AA AIO 8.004 with the six conditions listed for use of the Di -14 well. Pg 3 -4) Record of wellhead pressure and rate monitoring (Condition #1). Pg 5) Record of injected fluid source, type and volume (Condition 2). Pg 6) Plot of post- injection wellbore temperature survey as compared to the pre- injection survey (Condition #6). The inner annulus (IA) pressure was limited to 2000 psi throughout the disposal operations (Condition #3). The well didn't exhibit any indication of a change in mechanical condition during the disposal operations so Conditions #4 #5 were never needed. The post- injection temp survey did not show the temperature anomaly above the packer as you can see on the plot. We believe this is due to the reduced rate of injection over time resulting from the IA pressure limitations and the quality of the fluids injected into the well. Slower injection allows more time for the temperatures of the injected fluid to rise toward the temperatures of the surrounding rock and would decrease the size of the anomaly. As demonstrated by the temp survey, there isn't any indication that the injected fluids went outside of the approved disposal zones. If there are any questions, please feel free to call me. Larry 263 -7661 «Di -14 Post Injection Report 11- 23- 09.pdf» 11/24/2009 1 f i 1 1 i I J r I I i I` 1 f r r BEAN PARNELL, GOVERNOR 1 i IA lT I Imo., I r' Lfll 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 AIO 8.004 Mr. Larry Greenstein Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519 -6247 Re: South Middle Ground Shoal (S MGS) Unit 14 (PTD 1750660) Request for Ad- ministrative Approval Middle Ground Shoal Oil Pool, Dillon Platform Dear Mr. Greenstein: In accordance with Rule 9 of Area Injection Order (AIO) 008.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby approves Union Oil Company of California (Union)'s request for administrative approval to inject non- hazardous oil field fluids into the subject well. A wellbore temperature survey indicates that well S MGS Unit 14 exhibits a production casing liner leak, and thus does not meet the mechanical integrity requirement of AIO 008.000. The Commission finds that Union does not intend to repair the well at this time. However, injected fluid appears to be confined to subsurface strata that are approved by AIO 008.000 to receive injected fluids. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to inject non hazardous oil field fluids in S MGS Unit 14 is conditioned upon the following: 1. Union shall monitor wellhead pressures and injection rate continuously during in- jection; 2. Union shall submit to the AOGCC a post injection report of injected fluid source, type, and volume; 3. Union shall limit the inner annulus pressure to 2000 psi; 4. Union shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 5. After well shut -in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and AIO 8.004 September 15, 2009 Page 2 of 2 6. Union shall perform and submit to the AOGCC a post injection wellbore tem- perature survey. DONE at Anchorage, Alaska and dated September 15, 2009. OIL A 010K AlA .ice. �r ie Seamount, Jr. P Foe er t AA t ai an Commissioner AT1riN 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 re- consideration are FINAL and may be appealed to superior court The appeal MUST be filed within 33 days after the dale on which the Com- mission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by in- action, in which case the appeal MUST be fated 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 re- consideration 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 alter the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on re- consideration. As provided in AS 3I.05.080(b), "ItIhe questions tcvtewed 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 &11s 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. w AV D_at_a__Prorm Pump Report Alask aDillion2] •perator R ett Moncrie eport Date 26- Oct -09 e e Location 0 Days On Loc 7 Well DI -14 Injection Well Spud Date 19- Oct -09 Days Since 7 Injection Meter Cur. Cur, Cur. Depth Pump Pump Pump Date Time (MD) Turbine Turbine p n'asure Flow Rite Volume X12} (1 (11} (tt} tbpnl [DWI [psig} 25- Oct -09 19:15 0.0 0.00 0 0 25 -Oct -09 19:30 0.0 0.00 0 -1 25 -Oct -09 19:45 0.0 0.00 0 13 25 -Oct-09 20:00 0.0 0.05 0 390 25- Oct-09 20:15 0.0 0.05 1 414 25- Oct -09 20:30 0.0 0.05 2 390 25- Oct -09 20:45 0.0 0.05 2 323 25- Oct -09 21:00 0.0 0.05 3 320 25- Oct -09 21:15 0.0 0.05 4 320 25- Oct -09 21:30 0.0 0.05 5 319 25 -Oct -09 21:45 0.0 0.05 5 320 25 -Oct -09 22:00 0.0 0.05 6 318 25 -Oct -09 22:15 0.0 0.05 7 318 25 -Oct -09 22:30 0.0 0.05 8 318 25 -Oct -09 22:45 0.0 0.05 8 318 25 -Oct -09 23:00 0.0 0.05 9 318 25 -Oct -09 23:15 0.0 0.05 10 318 25 -Oct -09 23:30 0.0 0.05 11 317 25 -Oct -09 23:45 0.0 0.05 11 317 26 -Oct-09 00:00 0.0 0.05 12 309 26 -Oct -09 00:15 0.0 0.05 13 323 26 -Oct -09 00:30 0.0 0.75 14 371 26- Oct-09 00:45 0.0 0.81 24 666 26- Oct-09 01:00 0.0 0.47 36 872 26- Oct-09 01:15 0.0 0.45 42 620 26- Oct -09 01:30 0.0 0.55 49 778 26- Oct -09 01:45 0.0 0.48 57 676 26 -Oct-09 02:00 0.0 0.48 64 983 26- Oct -09 02:15 0.0 0.47 71 1,034 26- Oct -09 02:30 0.0 0.46 78 1,079 26- Oct -09 02:45 0.0 0.46 85 797 26 -Oct -09 03:00 0.0 0.00 92 949 26 -Oct -09 03:15 0.0 0.48 93 804 26 -Oct -09 03:30 0.0 0.53 100 846 26 -Oct -09 03:45 0.0 0.50 107 1,102 26 -Oct -09 04 :00 0.0 0.45 114 936 26- Oct -09 04:15 0.0 0.38 121 1,006 26 -Oct -09 04:30 0.0 0.31 127 1,295 26- Oct -09 04:45 0.0 0.46 134 1,229 26- Oct -09 05:00 0.0 0.00 140 1,120 26- Oct -09 05:15 0.0 0.25 144 1.115 26 -Oct-09 05:30 0.0 0.25 147 1,050 26 -Oct-09 05:45 0.0 0.06 150 1,108 26- Oct -09 06:00 0.0 0.00 151 1,006 omments I DataProTM Well Head Report AlaskaDiIlion2] Operator Rhett Moncrie port Date 26- Oct -09 Weatherto rd' Location j 0 Days On Loc 7 Well Dl-14 Injection Well Spud Date 19- Oct -09 Days Since 7 Well Head Cur. Cur. Depth cur' Outer Inner Date Time (MD) Tubing PING {7} Anulas Mules (8) P810 {2} (ft) [palm [pain) 25 -Oct -09 19:15 0.0 0 0 -9,999 25 -Oct -09 19:30 0.0 0 0 1 25- Oct -09 19:45 0.0 17 87 921 25 -Oct-09 20:00 0.0 372 94 1,032 25- Oct -09 20:15 0.0 377 94 1,037 25- Oct-09 20:30 0.0 363 90 1,025 25 -Oct -09 20:45 0.0 317 79 930 25- Oct -09 21:00 0.0 324 76 926 25 -Oct -09 21:15 0.0 324 75 925 25 -Oct -09 21:30 0.0 325 74 924 25 -Oct -09 21:45 0.0 324 74 924 25- Oct -09 22:00 0.0 324 74 923 25 -Oct -09 22 :15 0.0 324 74 923 25 -Oct -09 22:30 0.0 323 75 923 25 -Oct -09 22:45 0.0 323 75 923 25 -Oct -09 23:00 0.0 323 75 923 25 -Oct -09 23:15 0.0 320 76 923 25 -Oct -09 23:30 0.0 321 76 923 25 -Oct -09 23:45 0.0 322 77 922 26- Oct -09 00:00 0.0 271 77 922 26 -Oct -09 00:15 0.0 349 82 990 26- Oct -09 00:30 0.0 471 89 1,089 26- Oct -09 00:45 0.0 720 102 1,301 26 -Oct -09 01:00 0.0 770 96 1,258 26 -Oct -09 01:15 0.0 667 83 1,148 26 -Oct -09 01:30 0.0 730 83 1,156 26- Oct -09 01:45 0.0 780 82 1,160 26- Oct -09 02:00 0.0 823 82 1,168 26- Oct -09 02:15 0.0 875 81 1,157 26 -Oct -09 02:30 0.0 919 80 1,166 26- Oct-09 02:45 0.0 967 80 1,163 26 -Oct -09 03:00 0.0 982 77 1,134 26- Oct-09 03:15 0.0 890 73 1,050 26 -Oct -09 03:30 0.0 1,019 77 1,133 26 -Oct-09 03:45 0.0 1,068 79 1,183 26 -Oct -09 04:00 0.0 1,074 80 1,209 I 26- Oct -09 04:15 0.0 1,125 82 1,233 26- Oct -09 04:30 0.0 1,158 84 1,300 26- Oct -09 04:45 0.0 1,217 86 1,312 26 -Oct -09 05:00 0.0 1,184 86 1,321 26 -Oct -09 05:15 0.0 1,132 81 1,257 26- Oct -09 05:30 0.0 1,150 82 1,274 26 -Oct -09 05:45 0.0 1,118 80 1,247 26 -Oct -09 06:00 0.0 1,012 71 1,079 nts I Dillon Platform: S MGS Unit 14 PTD: 175 -066 Di -14 Disposal Well History Table 1: South Middle Ground Shoal (S MGS Unit 14) PTD 175 -066: Oct 25, 2009 Injection Summary Fluid Source Type Volume S MGS Unit 7 PTD:167 -069 Diesel 3.7 Barrels S MGS Unit 16 PTD: 194 -057 Diesel 3 Barrels S MGS Unit 17 PTD: 194 -056 NO Fluid N/A S MGS Unit 18 PTD: 194 -098 Hydrocarbon, Oil 6.7 Barrels S MGS Unit 13 PTD: 175 -074 Hydrocarbon, Oil 13 Barrels S MGS Unit 2RD2 PTD: 175 -007 Hydrocarbon, Oil 10.1 Barrels S MGS Unit 15 PTD: 176 -045 NO Fluid N/A S MGS Unit 3 PTD: 167 -028 Hydrocarbon, Oil 3 Barrels Platform: Rain Water, Deck drains Water 39 Barrels Platform: Water Rinsate, No Solids Water 18 Barrels Platform: Oil, water Diesel Flushed Fluids Diesel 25 Barrels Platform: Post water flush Water 25.2 Platform: Methanol, Freeze Protection Methanol 4.8 Table 2: Gas Bleed Volumes Fluid Source Type Volume S MGS Unit 7 PTD:167 -069 Gas Negligible S MGS Unit 16 PTD: 194 -057 Gas 2500 CF S MGS Unit 17 PTD: 194 -056 Gas 3789 CF S MGS Unit 18 PTD: 194 -098 Gas 43,471 CF S MGS Unit 13 PTD: 175 -074 Gas 3480 CF S MGS Unit 2RD2 PTD: 175 -007 Gas 630 CF S MGS Unit 15 PTD: 176 -045 Gas 66,900 CF S MGS Unit 3 PTD: 167 -028 Gas 1400 CF 2IPage (Chevron I Well :IDI 14 1 Field !Dillon 110 -28 -2009 Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 0 I I I I 1 500 i Pressure Temperature Profile Going in hole MD 1000 2. Well Shut -In 1500 2000 2500 3000 3500 4000 i +l W 4500 c 5000 E a 5500 l D 6000 6500 i 7000 7500 r 8000 8500 Nr I l I 41‘ 9000 1 9500 I i 10000 1 1 r E 40 50 60 70 80 90 100 110 120 130 140 150 160 Temperature (Deg. F) 10 Pressure Perfs 20" 13 -3/8" 9 -5/8" 3 -1/2" TBG 1 7" 10 -28 -09 Temp 8 -25 -09 Temp ~'~ ~ FW: Di-14 MIT Question (PTD #17506~ ~ Colombie, Jody J (DOA) From: Aubert, Winton G (DOA) Sent: Tuesday, September 15, 2009 6:33 AM To: Colombie, Jody J (DOA) Subject: FW: Di-14 MIT Question (PTD #1750660) Chevron request for admin approval is below. Winton From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Thursday, September 03, 2009 4:16 PM To: Aubert, Winton G(DOA); Regg, James B(DOA) Subject: FW: Di-14 MIT Question (PTD #1750660) Per our conversation, Winton, Page 1 of 2 Attached you'll find the rates & pressures recorded during the test injection operation on the 24t~' of August. «dillonwell14.pdf» Pius the ariginal overlay temperature survey done as part of the original authorization of disposal wells and oil pools (AR #$.2). «Di-14 Temp Survey 1-15-03 vs 12-17-02.jpg» In conjunction with the original e-mail (below) and this additional information provided, Union Oil Company of California would like to request the authorization from the State to utilize S MGS Unit #14 (Di-14 ar PTD #1750660) as a temporary disposal well as it is presently configured. The temperature anomaly above the packer (referenced below} is not indicated in the 2003 temperature survey. As the depth of this anomaly is within the C& D oil pools (both authorized disposal pools) and all oil pools (A through G) were authorized for disposal in AA #8.2, we believe that the temperature survey demonstrates full containment of the disposal fluids from below the B oil pool to the surface and therefore the well can safely be used to dispose of the anticipated bleed down fluids. Both rate and pressure will be monitored continuously throughout the active disposal operations and any indication of a secondary failure (significant rate increase without a pressure increase or significant pressure decrease without a rate decrease) would result in the well being shut-in, as is standard. Please call me if you have any other questions. If a face to face meeting would be of benefit, I would be glad to visit your office to discuss this request. Thankyou 9/15/2009 FW: Di-14 MIT Question (PTD #17506~ ~ Page 2 of 2 Larry 263-7661 From: Greenstein, Larry P Sent: Thursday, September 03, 2009 8:40 AM To: 'Jim Regg' Subject: Di-14 MIT Question (PTD #1750660) Hi Jim, Got an intriguing question about proving up the Di-14 well for temporary disposal use this fall. We are planning to do some bleed downs on the Dillon and Baker platforms this fall and wanted to resurrect one of the disposal wells on each platform to handle any produced fluids. I've been told the State has been notified of our intent to accomplish these well maintenance efforts. I got involved because the disposal wells haven't been used for quite some time and need MITs to be placed back in service. We are going to the Dillon platform first and we have an AA #8.2 approved for Di-12 & Di-14 to be used for temporary disposal. In the past, we had only used Di-12 for injection and had planned to do this again. When we rigged up on Di-12 to perform a test injection for the overlay temperature survey, we found we couldn't inject into the well at the anticipated pressures. We decided that it would be more efficient to prove up on Di-14 for disposal than to investigate and remedy the Di-12 wellbore for disposal. The test injection operation went well and we ran the overlay temp survey down past the packer depth, but not down over the perfs. What we found shows a temperature anomaly above the packer that I want to discuss with you. I included the overlay so that we can discuss this well and see how / if we can be allowed to use this for temporary disposal for Dillon fluids this fall. Our expectations are to need to dispose of less than 10- 15000 bbls of fluid (hopefully much less) which would still be well below half way to the 50000 bbl limit of the temporary disposal volume authorized by the AA. Attached is a schematic and the overlaid temperature survey. «WBD_DI-14.doc» «Di-14 Temp Survey 8-25-09 vs 8-3-09.jpg» Please call me when you have some time so we can discuss this well and our options. Larry 263-7661 9/ 15/2009 4Þ18 . . SARAH PALIN, GOVERNOR AI,ASIiA. ORAND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 17,2007 Ms. Jean Bodeau Waste Specialist Chevron North America Exploration and Production PO Box 196247 Anchorage, AK 99519-6247 Re: Administrative Approval Request South Middle Ground Shoal Unit; Dillon Platform Dear Ms. Bodeau: Chevron North America Exploration and Production ("Chevron") has requested authorization to inject up to 15,000 barrels of Class II non-hazardous fluids in Dillon Platform wells 12 (PTD 168-056) and 14 (PTD 175-066) located within the South Middle Ground Shoal Unit, Cook Inlet. The date of Chevron's request was May 10, 2007. The Alaska Oil and Gas Conservation Commission ("Commission") has already authorized the injection of up to 50,000 barrels of Class II non-hazardous fluids into these 2 wells under Area Injection Order Administrative Approval 8.2 ("AID 8.2") dated January 29, 2003. Additional clarification of fluids eligible for injection under AID 8.2 was provided to Chevron in administrative approval AIO 8.3 dated March 4, 2003 and in a letter dated March 23, 2006. Commission records indicate less than 8,000 barrels of Class II fluids have been injected into Dillon 12 since AID 8.2 was approved; Dillon 14 has remained shut in. Chevron's request is a continuation of work initiated under AIO 8.2 requiring no further action by the Commission. You must demonstrate the mechanical integrity of each well with a baseline temperature survey prior to initiating any additional injection and follow up with a subsequent survey immediately following the injection of not more than 1,000 barrels of fluid. Sincerely, Ç!¡~ Commissioner =*17 350 300 250 200 150 00 50 vs 2 vs 000 900 800 700 600 500 400 300 200 00 0 '<t !O !O !O !;2 0 0 !;2 -- -- '""" '""" 0 0 M ~ M M Ñ M -- 14 ID o -- .- ~ M .. ~ ---~-~. ~~~-----_.._._._-~,.^^..__._~~-,._._~~-~-- 1 ·' f . 1 #16 .' . . Chevron === Jean Bodeau Waste Specialist Chevron North America Exploration and Production 909 West 9th Avenue P.O. Box 196247 Anchorage, AK 99519-6247 Tel 907 263 7803 Fax 907 263 7901 Cell 907 360 7929 Email BodeauJ@chevron.com RECEIVED MAY 1 1 Z007 May 10, 2007 Alaska Oil & Gas Cons. Commission Anchorage Mr. John K. Norman, Commissioner Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 RE: REQUEST FOR ADMINISTRATIVE APPROVAL TO AIO 8.2 FOR DILLON PLATFORM Dear Mr. Norman: Administrative Approval No. AIO 8.2, issued by AOGCC on January 29, 2003 authorized Unocal to dispose by injection up to 50,000 barrels of Class II non-hazardous fluids into the upper portion of the Tyonek Formation in wells Di-12 and Di-14 on the Dillon Platform in the Southern Portion of the Middle Ground Shoal. The approval was issued to enable disposal of fluids from cleaning and removal from service of equipment associated with the Dillon Platform. The fluids approved under AIO 8.2 include unfiltered inlet water, produced water, produced oil, sludge, triethyleneglycol, paraffin, and asphaltenes. Administrative Approval No. AIO 8.3, issued by AOGCC on March 4, 2003, authorized injection disposal of deck drainage in addition to the previously authorized materials. In 2003, a total of approximately 6,518 barrels of Class II fluids were disposed in Di-12, and Di- 14 was maintained as a backup. I am writing to request authorization to dispose of up to 15,000 barrels of Class II non- hazardous fluids in wells Di-12 and/or Di-14 during 2007. If this full volume were to be disposed, the total injected volume would still be well within the limit authorized in AIO 8.2. The fluids will be generated during cleaning operations on 8 pipeline that runs from XTO C platform to the Dillon Platform. The 8 Pipeline has been idle since 2001 and contains no oil. It is being cleaned in preparation for abandonment. In addition, fluids may be generated during operations on C Pipeline. Repairs are planned for the C Pipeline to enable cleaning in advance of abandonment. However, if repairs are not able to be completed, then subsea pig-launchers would be installed to allow cleaning, and fluids would need to be sent to the Dillon Platform for disposal. The anticipated fluids include clean seawater, hydrocarbon residue, diesel, xylene, and soap. There may also be produced water, produced oil, sludge, triethyleneglycol, paraffin, asphaltenes and deck drainage due to rainfall on the platform. Midcontinent/Alaska SBU/Chevron North America Exploration and Production htlp:/ /www.chevron.com . . In 2003, temperature surveys were used to confirm that the casing was not leaking and that all fluid was exiting into the intended zones. After receiving conceptual approval from AOGCC to inject the described fluids in these wells, we propose the following procedure to confirm mechanical integrity for each well where injection will be performed: 1000 bbl of fluid will be injected followed by a temperature survey to reconfirm that all fluid is exiting into the intended zones. Upon AOGCC approval, injection will recommence. The wells are not currently in use and there are no plans to reactivate the Dillon Platform for production. We anticipate the project will take place no earlier than July 1, 2007. Please contact me at (907) 263-7803 or by email atbodeaui@chevron.comif you require additional information. Thank you very much for your consideration and assistance. Best regards, J n Bodeau Waste Specialist 4t: /'5 Treated Wastewater for EOR . . Ms. Sullivan - Chevron's request to divert the treated the Dolly Varden Platform waterflood is approvals - no further authorization is to A letter from the Commission dated December 4, 1992 approves treated sanitary wastewater as an enhanced recovery injection fluid. That letter does not restrict the source of treated sanitary wastewater for enhanced recovery injection in the Trading Bay Unit. The sanitary waste stream from ongoing work at the Dillon Platform is being treated by a small omni-pure plant. My understanding from our phone conversation this afternoon is Chevron has found it difficult to meet the strict effluent limits required for overboard discharge under NPDES. Chevron has identified the Dolly Varden platform active water flood (currently injecting filtered inlet water and treated wastewater) as a suitable source for injecting the Dillon treated wastewater. Such injection is consistent with the Commission's December 4 letter and with Rules 1 and 9 of AlO 5. Jim Regg AOGCC 1 of 1 10/30/20068:26 AM #14 ) ) FRANK H. MURKOWSKI, GOVERNOR AI¡ASIiA OIL AltO GAS CONSERVATION COlWllSSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 March 23, 2006 Ms. Laura L. Hammond Waste Management Coordinator U nocal Alaska 909 West 9th Avenue Anchorage, AK 99501 Dear Ms, Hammond: Unocal Alaska ("Unocal"), by letter dated March 21, 2006, requested confirmation that liquid wastes developed from gas/oil gathering line cleaning and from well plugging may be legally injected into service wells previously approved for limited disposal of Class II wastes on South Middle Ground Shoal Dillon ("Dillon") Platform offshore Cook Inlet. The Alaska Oil and Gas Conservation confirms that the liquid wastes described in your letter may be legally disposed into the approved wells on Dillon Platform. Production operations ceased on Dillon in December 2002 and Unocal "cleaned" the production equipment on board the platform in early 2003. Prior to initiating the cleaning operations, Unocal sought administrative approval under Area Injection Order ("AIO") 8 to dispose of liquid wastes in either of two existing enhanced recovery ("EOR") wells on the platform. Injecting wastes into an EOR well is prohibited by Commission regulations. However the Commission determined that the liquids, mostly water and oil with some detergents, would not be damaging to the reservoir. AIO 8.2 issued January 29, 2003 authorized disposal of up to 50,000 barrels of liquid wastes into either Di-12 or Di-14. The planned cleaning operations were performed during February and March 2003 with a total of 6,347 barrels of waste liquid injected into Di-12. No waste fluid has been injected into Di-14. At this time Unocal is proposing to conduct downhole plugging operations on up to 16 wells on Dillon and purge the subsea oil and gas gathering lines connecting Dillon with XTO Platform A to the northwest. The anticipated wastes include fluids circulated from wells (filtered and unfiltered Inlet water, cement and small quantities of oil) and fluids circulated from the subsea gathering lines (unfiltered Inlet water and small quantities of oil and condensate). As allowed by AlO 8.3, Unocal will also dispose of any deck drainage resulting from rainfall onto the platform. Some solid wastes may be generated by these operations. However Unocal is not seeking to dispose of solids on board Dillon. Nor is Unocal seeking approval to inject domestic sanitary wastes that may be generated by the crews performing the operations. ) ) Ms. Laura L. Hammond March 23, 2006 Page 2 of2 The Alaska Oil and Gas Conservation Commission has completed its review of your request. Liquid wastes resulting from the described well plugging and flowline cleaning operations qualify as Class II fluids and may be injected into either Di-12 or Di-14 according to Ala 8 and Administrative Approvals Ala 8.2 and 8.3. Prior to resuming injection operations, Unocal must confirm the continued integrity of the injection wells with a mechanical integrity test as outlined in Rule 6 of AIO 8. Please have your operations personnel contact Jim Regg at 793-1236 to schedule an Inspector for witness. As provided in AS 31.05.080(a), within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless reconsideration has been requested. , Alaska and dated March ~ 2006 ~ aniel T. Seamount, Jr. Commissioner cc: Tim Brandenburg, Unocal Evan Harness, Unocal Philip M. Ayer AIO 8.3 March 4, 2003 Page 2 of2 ) Pursuant to Rule 9 of Area Injection Order No.8 deck drainage is an authorized fluid for disposal in Dillon Platform wells Di-12 and Di-14 within the MGS A, B, C, D, E, F, and G Oil Pools. The total volume authorized for disposal by AIO 8.2 remains 50,000 barrels. DONE in Anchorage, Alaska this 4th of March 2003. ~ Daniel T. Seamount, Jr. Commissioner Æ~Þj ~/~ - ~ Randy Ruedrich Commissioner BY ORD.ER OF THE COMMISSION ~ '''.; .. ........ ..." ',:.t , '-I' I', I #13 ') ) Chevron III Laura L. Hammond Advising Environmental Engineer & Waste Management Coordinator Union Oil Company of California 909 W. 9th Avenue Anchorage, AK 99501 Tel 907 263 7898 Fax 907 263 7901 Emaillhammond@chevron.com RECEIVED MAR 2 1 2006 March 21, 2006 Alaska Oil & Gas Cons. Convnission Anchorage Commissioner John Norman Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Re: Description of Proposed Work on Dillon Platform in 2006 and Future Dear Commissioner Norman: The purpose of this document is to communicate to you the scope of work proposed on Dillon Platform during 2006 and subsequent work seasons by Union Oil Company of California (UOCC), an indirectly owned subsidiary of Chevron Corporation, and the disposition of the associated waste streams. Attached please find "Description of Proposed Dillon Platform Well and Pipeline Work and Related Waste Disposal." Mr. Tom Maunder recommended that this information be sent to you to secure your concurrence that the fluids associated with the gathering line cleaning and the well work may legally be injected into Dillon Wells #12 and #14 under existing permitting and authorizations. Thank you very much for your consideration of these matters, and please contact me at (907) 263-7898 if you would like additional information about the proposed work. Best regards, ~~Ä-#~ Laura L. Hammond Attachment: 2 pages Cc: Evan Harness Faye Sullivan Mike Lott Tom Maunder, AOGCC Union Oil Company of California I A Chevron Company http://www.chevron.com ) ) Description of Proposed Dillon Platform Well and Pipeline Work and Related Waste Disposal Purpose Project Type and Planned Timeline Waste Streams by Project and Planned Disposition The purpose of this document is to provide an overview of the proposed Vnion Oil Company of California (VOCC), an indirectly owned subsidiary of Chevron, Dillon Platform work scope as requested by Mr. Tom Maunder. The following is a list of the project types and the possible timeframe: Year Pro.iect 2006 Well Work up to 16 wells (Most Likely 12 - 13) Future Clean and abandon Dillon Pipelines Future Well Work up to 16 wells (Most Likely 3 - 4) The following table delineates the expected waste streams and their planned disposition for each type of project: Project/Origin Type Waste Stream Disposition Well Work Fluids Inject in Well # 12 or # 14 Deck Drainage Fluids Inject in Well #12 or #14 Clean and abandon Fluids Inject in Well # 12 or # 14 Dillon Pipelines Clean and abandon Solids from Production Offsite disposal at Commercial Dillon Pipelines Test Separator and Disposal Vendor, likely G&I in Shaker Texas at N ewpark, or contingent disposal if VOCC has a Class II (or Class I) Disposal Well set up for G&I such as NNA #2 Clean Baker Gas Pipeline Residual Trapped Gas Vent, maximum amount based on total pipeline volume, actual volume to be reported Both Pipeline & Well Oily Burnable Solids Incineration by Envirotech, Work Nikiski, AK Both Pipeline & Well Greywater NPDES Discharge or ISO Tank Work to Onshore Disposal by Envirotech Both Pipeline & Well Blackwater/ sewage Omni-Pure System followed by Work NPDES Discharge Both Pipeline & Well Clean Trash KPB Landfill Work Continued on next page ') ) Description of Proposed Dillon Platform Well and Pipeline Work and Related Waste Disposal, Continued Only Fluids To Only fluids will be injected into Well # 12 and/or Well # 14; DOCC does not Be Injected plan to mobilize Grind and Inject equipment; we plan to containerize solids captured in shakers and separators and ship them off of the Platform for approved disposal. #12 ) J /~\ ~l?' . .' f'~\ 4,"",,";:J '1'-' l .i,.I!. U '.' ji ..ð\. ',' ...1 '. :.r ," '/. ./i'\ \ j 1 "F "'.'....\. .. :.' ...',,' '.\ .II, .', '.¡ ·.:.1 ..' . "\ 'U' ¡'-I:,' " 1nJ ,I .. ·1 /--\ \ ·U; ,Il; \~'·L.'W·· ~ r~u.\\ .¡'" '¡:::1 .j' I,; ; ~I 6 ·W:I:"i , ;Iil \.,. .' ',W In n ¡tr\ (' rLJ I j',\j¡ . ':1\ '. "" /:~\!i !,~, \ :-"'\ :'\ '., ",II" I J' " ."1 i ) J..J '1...;\ ~ LJ i.....:! \,.:::../ tT\ //J\ LTlJ FRANK H. MURKOW5KI, GOVERNOR A"~A~HA. OIL AlU) GAS CONSERVATION COJDIISSION 333 W. ]TH AVENUE, SUITE 100 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 inj ection 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 Integritv 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 lO-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 "Administrati ve Mechanical Failure and Action" Integrity" Confinement" Area Injection Orders AIO 1 - Duck Island Unit 6 7 9 AIO 2B - Kuparuk River Unit; Kuparuk River, 6 7 9 Tabasco, Ugnu, West Sak Fields AID 3 - Prudhoe Bay Unit; 6 7 9 Western Operating Area .-~.. AIO 4C - Prudhoe Bay Unit; 6 7 9 Eastern Operating Area AIO 5- Trading Bay Unit; 6 6 9 McArthur River Field AIO 6 - Granite Point Field; 6 7 9 Northern Portion AIO 7 - Middle Ground 6 7 9 Shoal; Northern Portion AIO 8 - Middle Ground 6 7 9 Shoal; Southern Portion AIO 9 - Middle Ground 6 7 9 Shoal; Central Portion AIO 1 OB- Milne Point Unit; Schrader Bluff, Sag River, 4 5 8 Kuparuk River Pools AIO 11 - Granite Point 5 6 8 Field; Southern Portion AIO 12 - Trading Bay Field; 5 6 8 Southern Portion AIO 13A - Swanson River 6 7 9 Unit AIO 14A - Prudhoe Bay 4 5 8 Unit; Niakuk Oil Pool -- AIO 15 - West McArthur 5 6 9 ) ) Affected Rules "Demonstration of "Well Integrity "Administrative Injection Order Mechanical Failure and Action" Integrity" Confinement" River Unit Ala 16 - Kuparuk River 6 7 10 Unit; Tam Oil Pool 6 8 Ala 1 7 Badami Unit 5 Ala 18A - Colville River 6 7 11 Unit; Alpine Oil Pool AIO 19 - Duck Island Unit; 5 6 9 Eider Oil Pool AIO 20 - Prudhoe Bay Unit; 5 6 9 Midnight Sun Oil Pool AIO 21 - Kuparuk River 4 No rule 6 U nit; Meltwater Oil Pool AIO 22C - Prudhoe Bay 5 No rule 8 Unit; Aurora Oil Pool 6 9 AIO 23 Northstar Unit 5 AIO 24 - Prudhoe Bay Unit; 5 No rule 9 Borealis Oil Pool AIO 25 - Prudhoe Bay Unit; 6 8 13 Polaris Oil Pool AID 26 - Prudhoe Bay Unit; 6 No rule 13 Orion Oil Pool I Disposal Injection Orders DID 1 - Kenai Unit; KU No rule No rule No rule WD-l DIO 2 - Kenai Unit; KU 14- No rule No rule No rule 4 DIO 3 - Beluga River Gas No rule No rule No rule Field; BR WD-l DIO 4 - Beaver Creek Unit; No rule No rule No rule BC-2 DIO 5 - Barrow Gas Field; No rule No rule No rule South Barrow #5 DIO 6 - Lewis River Gas No rule No rule 3 Field; WD-l DIO 7 - West McArthur 2 3 5 River Unit; 'WMRU D-1 DIO 8 - Beaver Creek Unit; 2 3 5 BC-3 DIO 9 - Kenai Unit; KU 11- 2 3 4 17 D 10 10 - Granite Point 2 3 5 j Field; GP 44-11 Affected Rules "Demonstration of "Well Integrity "Administrative Injection Order Mechanical Failure and Action" Integrity" Confinement" DIO II - Kenai Unit; KU 2 3 4 24-7 010 12 - Badami Unit; WD- 2 3 5 1, WD- 2 010 13 - North Trading Bay 2 3 6 Unit; 8-4 DIO 14 - Houston Gas 2 3 5 Field; Well #3 010 15 - North Trading Bay 2 3 Rule not numbered Unit; 8-5 010 16 - WestMcArthur 2 3 5 River Unit; WMRU 4D DIO 17 - North Cook Inlet 2 3 6 Unit; NCrU A-12 DIO 19 - Granite Point 6 Field; W. Granite Point State 3 4 17587 #3 DIO 20 - Pioneer Unit; Well 3 4 6 1702-150A \VDW 010 21 - Flaxman Island; 3 4 7 Alaska State A-2 DIO 22 - Redoubt Unit; RU 3 No rule 6 Dl --_..-.. DIO 23 - Ivan River Unit; No rule No rule 6 IRU 14-31 DIO 24 - Nicolai Creek Order expired Unit; NCU #5 DIO 25 - Sterling Unit; SU 3 4 7 43-9 DIO 26 - Kustatan Field; 3 4 7 KFl I I -- Storage Injection Orders S10 1 - Prudhoe Bay Unit, No rule No rule No rule Point Mcintyre Field #6 SIO 2A- Swanson River 2 No rule 6 Unit; KGSF # 1 SIO 3 - Swanson River Unit; 2 No rule 7 KGSF #2 Enhanced Recovery In_i ection Orders EIO 1 - Prudhoe Bay Unit; No rule 8 Prudhoe Bay Field, Schrader No rule Bluff Fonnation Well V-I05 ) ) Affected Rules Inj ection Order "Demonstration of "Well Integrity "Administrati ve Mechanical Failure and Action" Integrity" Confinement" EIO 2 - Redoubt Unit; RU-6 5 8 9 I 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM STATE OF ALASKA ADVERTISING ORDER $EEBpTJ'OMr;:()~·INYOICE~PQ~ES$ NOTICE TO PUBLISHER ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AO-02514016 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COpy OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC 333 West ih Avenue, Suite 100 Anchorage,AJ( 99501 907-793-1221 AGENCY CONTACT DATE OF A.O. ~t-:r .:,{" ')7 7004 PCN R o M Iodv C:oJomhie PHONE (907) 791 - 1 7.71 DATES ADVERTISEMENT REQVIRED: T o J oumal 0 f Commerce 301 Arctic Slope Ave #350 Anchorage, AK 99518 October 3, 2004 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE OATES SHOWN. SPECIAL INSTRVCTlONS: United states of America AFFIDAVIT OF PUBLICATION REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. division. Before me, the undersigned, a notary public this day personally appeared 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 Colombie <jody _ colombie@admin.state.ak.us> Date: Wed, 29 Sep2004 13:01 :04 -0800 To: undisclosed-recipients:; BeC: Cynthia B Mciver <bren_mciver@a~in.state.ak.us>, Angela Webb <angie _ webb@admin.state;~.us>, ·Robert· E Mintz. <robert _11lin~@Iaw~state;*.us>, Christine Hansen<c.hansen@iogcc.~tate.9k.us>, Terrie Hubble <hubbletl@bp.com>, Sondra Stewman <StewmaSD@BP.com>, Scott & Cammy Taylor <ståylorC$alaskª.n.~t>,·stanekj <stanekj@unocal.com>, ecolaw <ecolaw@trustees.org>, roseragsdale <ro.seragsdale@gci.net>, trrnjrl <trmjr 1 @aol.com>, jbriddle ·<jbriddle@marathonoiI.com~, rockhill <rockl1ill@aoga.org>, shaneg <shaneg@eve~green~as.com>, jdarlington <jdarlington@forestoi1.com>,:.:ri~lspn <krielson@petroleurtinews.com>, cboddy <cboddy@usib¢U~.co~>, 1~1ark DaJtpn . ,. <mark..dalton@hdiinc.com>, Shannon D()nnelly <shannon.donnellY@conocophiIlips.com>~. '~1Y1arkP. Wqrcester" <tnark.p..worcester@conocophil1ips~com>, "JerrY C. D~thlefs" . '.. ." <jerry.c.dethlefs@conocophillips.com> ,Bob <bob@inletkeeper~org>,. wdv <wdv@dnr.st~tè.ak. us>, tjr <tjr@dnr~state.ak~ u~>,. bbritch <bbritch@alaska.net>, mjnelson <mjnelson@pu:rvingertz.com>, Charles O'Donnell <charles.o'donnell@veco.com>, "RandyL. Skillern" <SkilIeRL@BP.com>, "Deborah J. Jones" <JonesD6@BP.com>, "Paul G. Hyatt" <hyattpg@BP.c.om>, "Steven R.Rossberg" <RossbeRS@BP.com>, Lois <lois@inletkeeper.org>, Dan Bross<kuacnews@kuac.otg=>, Gordon Pospisil <PospisG@BP . com>, "Francis S. SoID.i1:\er" <SommerFS@B1? . com>, Mikel Schultz <Mike1.Schultz@BP.com>, "NickW.Glover" <GloverNW@BP.com>, "Daryl J. Klepp-in" <K1eppiJ)E@f3P.com>, "Janet D. Platt" <~lattJD@BP.com.>, "Rosanne M. Jacobsen" <J acobsRM@BP.com>, ddorikel <ddonkeI@cttrr~com>, Collins Moúnt <collins~mount@revenue.state.ak.us>, Mckay <mckay@gci~I)et>, ~arbara F Fullmer <barbara.f.fullmer@conocophillips.com>, bocastwf <bocastwf@bp¡çom>, Charles Bark~r : <barker@usgs.gov>, dOllg_ schultze <doug_ schultze@xtoenergy.com>,Hank Alford " <hank.alford@exxonmobil.com>, Mark Kovac <yesno l@gci.net>~ .gspfoff '. <gspfoff@aurorapower.com>, GreggN ady <gregg.nady@shelLcom>,FredSteece <fred.steece@state.sd.us>:, rcrotty <rcrotty@ch2m.com>,j-ejones ·<jejones@aurorapower.com>, dapa <dapa@alaska.net>, jroderick <jroderick@gci.net>, eyancy <ey~cy@s·ea1~tite.net>, "James M. Ruud" <james.m.ruud@conocophillips.com>, Brit Lively <map~askà@*.net?:, jah <jah@dnr.state.ak..us>,. Kurt EDIson <k:urt_oIsori@legis.state.ak.us>, h~onoje <buònoje@bp.com>, Mark H~ley <mark _ hanley@anadarko..com>, loren _lernan <loren _leman@gov.state.ak.us>, Julie Houle<julie_houle@dnr~state.ak.us>, John W Katz<jwkatz@sso.org>, Suzån J Hill . <suZan _hill@dec.state.ak.us>, tablerk <tablerk@unoca1.com>, Brady <brady@aoga.()rg>, Brian Havelock <beh@dnr.state.ak.us>, bpopp <bpopp@borough.kerÚli.ak. us>, Jim WhIte <jimwhite@satx.rr.com>, "John S. Haworth" <john~s.haw<?rth@exxonmobîl.com>, marty <marty@rkindustrial.çom>, ghammons <ghammox¡s@aotcOf[l>, rmcle~ . <nnclean@pobox.aIaska.net>, mkm7200 <mkm7200@aoLcom>" Brian Gillespie <ifbmg@ua&alaska.edu>, Dàvid L Boel~ns <dboelen,s@áu.rorapower.com>,Todd Du~kee <TDURIŒE@~G.com>, Gary Schultz <gary _ schultz@dnr~stateaak:.US>, Wayne :Rancier <RANCIER@petro-canada.ca>, ~'¡ll Miller <Bill_ Miller@xtoalas~a.cQri1>" j3raridón Ga~on <bgagnon@brenalaw.com>, Paul Winslow <pmwmslow@forestoil.coÏri>, GarrY' Catron <ç~~~~p;r~p:~Q~~~§~~~~'9(}g~~,~~,<;copelasv@bp~com>, Suzanne' Allei~. .... <s't1}~¥~~~~~~~µ.~r~··~?111»'~~~ill: J:)'ir~s:<kristÙl_ dirks@dnr.state.ak.us>, Kaynell Zeman ~~jž~~ªª(@~~à~Þ~9~t.Ç~n1>,J~H#^~~vV~r:<John.Tower@eia.doe.gov>, Bill Fo.wIer. .>. . .' ...... <ßiH~.JjpWlër@àttaqáikø.GØM>,VaùgtmSwartz·<Ya~~~swartz@rhc.cl11i:~ºItI:::-:~$e€)t;tçr(11l~Wi.c~ 10f2 9/29/2004 1: LO PM Public Notices <scott.cranswick@mms..gov>, Brad McKim. <mckimbs@BP..com> Plea.se find the attached Notice and Attachment for th~I?r9:poSed amendment of 1].ndergroundinjection orders and the: Public Notice Happy Valley #10. Jody Colombie .,......,.,,,,, '"''''':''..:''...".",.........".".,,''''''''' : . ... .... >'. '. .. .'. . ....!Content-Typç: appficationlmsword ¡MechanlcallntegrItyproposal.docJ.' ........ ......... ........... ............... b· .... 6"4" ; eontent~Encod.mg: ·ase ". . ¡'''' : C()ntent~1rype: åpplicationlmsword Mechanical Integrity of Wells Notice.dôc! .... ....... .......... ..... .................... .... "b'" "64.. ! Content-Encoding:' ·ase ..' '. . ..... ,..... ...... . .... . .'. : Content-Type: application/ms"Word HåppyVaUeylO ßearlngNotlce.doc '. . ....... ......... ..... ..... .... k ." .6 ' - . . ¡ Content-El1ç()tlbtg: vas~. 4 . " ". '. ,'" ....,_~.. ~ "~ _,_~ '. ..,.... """_""'~'~' _._,_",,_,_,.,~,..~. .", ...... ~."_..",,._,. _.. .,._u ~''''_.'''' ,. ,_". .....,~ ....'..... ... ..~ __......... .,.,"......,._,..._' _.....'_,"~ . ._ ""W_.',,~_...' _-..:-.__. _w'" ._~~,-~"._",_'_,,",,"'.w_ .,.__.......wow.._.__... '. .. u._~.. ,_._", _ w.. "._..~ ___~ 20f2 9/29/2004 I: 10 PM Public Notice ) ) Subject: Public Notice From: Jody Colombie <jody _ colombie@admin.state.ak.us> ])ate: \yecl? 29 S~p ?004 12:55:26 -0800 T~::··l'.t?~#1'@å.ta{~t\?j99m~1·:coiJ;¡··.'.. 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 Ad Order form. doc Content-Encoding: base64 " -.,.-...... .....-......-... .... ~........._.~._"."._.~.. l of 1 9/29/2004 1: 10 PM Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 /1ct¡/¿:d 1(//(t1~ David McCaleb I HS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 John Levorsen 200 North 3rd Street. #1202 Boise, ID 83702 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle. WA 98119-3960 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Jack Hakkila PO Box 1 90083 Anchorage, AK 99519 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 James Gibbs PO Box 1597 Soldotna. AK 99669 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna. AK 99669-2139 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 North Slope Borough PO Box 69 Barrow, AK 99723 · [Fwd: Re: Consistent Wording for Injection }rs - Well Integrity... ) Subject:.·[Fwd: Re:. ConsistentWor4Ù).~..f()t II:j~etiorl.OrdeFs··-Wêll*t¢gpitY(R.eviseq)] Ffom:. J OM N orman<john_l1ol"1Ilan($a4min.state,.ak.u~> Date: Fri,010ct 200411:09:26;;;0800 t9';..·JQa¥...T··..·~9ÍQWbjè··<JoayjŠ()iötÌîþi~@ådtni~·~·~ÿ~te~.ák.µs~.···,.,· more -------- 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 l11intz~law.state.ak.us> To:jim regg~admin.state.ak.us CC :dan seamount(C4admin.state.ak. us, john norman@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~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 abQut 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 regg(c4admin.state.ak.us> 8/17/20044:33:52 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 I of 2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injection ers - Well {ntegrity ... - 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 DrOs 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 ofterrns 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 Norrnan@admin.state.us> Commissioner Alaska Oil & Gas Conservation Commission 20f2 10/212004 4:07 PM .[Fwd: Re: Consistent Wording for Injection ( )rs - Well Integrity... ) Subject: [Fwd: Re:Consistent W ordingfor Injëction Grders ~ Well Iritégrity(I{evised)] F'rf,nn: John Norman <johri_norman@admin~state.ak.t1s> Dåte: Fri, 01 Oct 2004 11 :08:55 -0800 19;·lp~~·.j·..€()I9**þiè··.···$jq9Y~c()i·ó~1?ì¢@~dm~~·..~~~te.-i3.t<.1ts>·.···· . 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(ã¿law.state.ak.us> To:dan seamount(ã¿admin.state.ak.us, jim regg(ã¿admin.state.ak.us, john norman(ã¿admin.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 red lines on the second document attached. »> James Regg <jim regg@admin.state.ak.us> 8/17/20044:33:52 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 Sf. 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 DIG 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 10f2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording for Injection ~rs - Well Integrit,y ... - 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 ofterrns 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", "USD\Vs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. N·onnan <John Norman(åJadmin.state.u~> Commissioner . Alaska Oil & Gas Conservation Commission . Content-Type: application/msword Injection Order language - questions.doc Content-Encoding: base64 Content-Type: applicationlmsword Injection Orders language edits. doc Content-Encoding: base64 20f2 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% 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 everv four years thereafter (except at least ünce everv twü veal'S in the case of a slurry iniection \vcll), and before returning a~~:yll~~Lservice foUo\vine after a workover affecting mechanical integrity, and at l~Q~;t once every '1 year~; \vhik uctively in~. For ~;!urry i-fljection ,-,,'ells, the tubing/casing .mr..H-1-1:ts-f:rH:ts-i--B-e--t:sted tlir mechanical integrity è\'ery 2 Ye-aFS-:: Unless an alternate ¡'Deans is approved bv the Cornnlission. Inechanical integrity Inus! be demonstrated bv a tubing pressure test using a +he MI+-surface pressure of must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, that ffH±St-show~ stabilizing pressure that does~lnd Inay not change more than 10%- percent during a 30 minute period. -Afl.y altenlate nlean::; of delnon~trJ.ting 111cchanical inte-gfl{ÿ---HH:l-s-t-l7€-·approvcd by tho COlnnlis~ion-; The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement Except as othenvise provided in this rule, +1he tubing, casing and packer of an injection well must Ek.~cfffi.e-lnaintain integrity during operation.\Vhenever any pressure conlffiunication, leakage or lack of inìection zone isolation is indicated bv injection rate. operating pressure observation, test, survey, log. or other evidence, t+he operator 'ffH±S-f-shall immediately notify the Commission and submit a plan of corrective action on ª-Forrn 10-403 for Commission approval.:. ~~-v"L~sure COlTIlTIUnication, lèakage or lack of inj~ction zone isolation is indicated boy injection rate, operating pressure obseryv-atíon, test, survey. or log. The operator shall shut in the well if so directed bv the Comn1ission. The operator shall shut in the \-vell \vithout arvaiting a response from the Comlnission if continued operation Vv'ould be unsafe or would threaten contamination of freshwater~'"T€ is no threat to freslrvvater, injection tnay continue until the C01TIlTIi:;sion requires the \\'ell to be shut in ør ~~ecared. Until corrective action is successfullv completed, ^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. JFwd: Re: [Fwd: AOGCC Proposed WI Lant ~ for Injectors]] ) ~1I~~ect: [Fwd: Re: [Fwd: AOGCCProposed WI Language for Injectors]] ~l"gm:WintonAubert <winton~aubert@admin.state.ak. us> Y~~~:,!Þ,11,,4~qc~fOq4Q9:4~è:??~O~.QO, " "'.. '.' I~;:'.'lg<I.Y:'J",.Ç~:lçï!ì~;i¥:..,.'§j()ø¥d¢olt?Í11bi~@~~r#Úil.§~~t~.~..ÚŠ? 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 -------- AOGCC Proposed WI Language for Tue, 19 Oct 2004 13:49:33 -0800 Engel, Harry R <EngeIHR@BP.com> winton aubert@admin.state.ak.us Injectors Subject: Date: From: To: 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: liThe 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 Lanf ~ for Injectors]] returnj.ng a well to service following a workover affecting mechanical integrity. II 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 lIafter" was substituted for IIbeforell, 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, log, or other evidence, the operator shall * immediately*_** notify the Commissionll 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 Ai Denis, John R (ANC); Miller, Mike E; McMullen, John C Subject: FW: Public Notices FYI -----Original Message----- From: Jody Colombie [ mailto:jody colombie@admin.state.ak.us Sent: Wednesday, September 29, 2004 1:01 PM Subject: Public Notices 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 of3 10/28/2004 II :09 AM #11 RE: Unocal- Dillon Platform: Di-14 10403 Approval for Diaposal ) ) Subject: RE: Unocal- Dillon Platform: Di-1410 403 Approval for Di!posal Date: Thu, 13 Feb 2003 09:55:38 -0800 From: "Ayer, Phil M -Alaska" <pmayer@unocaLcom> To: "'Tom Maunder'" <tom_maunder@admin.state.ak.us> CC: "Dolan, Jeff J" <dolanjj@unocaLcom> Tom, Here is Di-14 injectivity test details performed on 1/14-15/03. Phil Phil Ayer Unocal Corporation 909 W. 9th Ave, Anchorage, AK 99515 email: pmayer@unocaLcom 907-263-7620 (work) 907-250-2711 (cell) 907 -263-784 7 (fax) > -----Original Message----- > From: Ayer, Phil M -Alaska > Sent: Wednesday, February 12, 2003 3:02 PM > To: 'Tom Maunder' > Cc: Dolan, Jeff J > Subject: RE: Unocal- Dillon Platform: Di-14 10403 Approval for Diaposal > > I understand and agree with your comments on increasing rate and the > pressure response one might see and what it might mean. I am taking this > into consideration by initially limiting the pressure to 2000 psig. > > The call from the field was tied to the expected rain and the effects it > might have. I am getting clarification but I expect that we may need Di- > 14. > I appreciate your attention the to Di-14 10-403 and I will keep you > abreast of any information I get. > > Feel free to call me at home or cell with response if after work hours. > > Phil > > Phil Ayer > Unocal Corporation > 909 W 9th Ave, Anchorage, AK 99515 > email: pmayer@unocal.com > 907-263-7620 (work) > 907-250-2711 (cell) > 907-263-7847 (fax) > > > > -----Original Message----- > > From: Tom Maunder [mailto:tom maunder<éD.admin.state.ak.usl > > Sent: Wednesday, February 12,20032:50 PM > > To: Ayer, Phil M -Alaska > > Subject: Re: Unocal- Dillon Platform: Di-14 10403 Approval for Diaposal » > > Phil, > > I will try to get back to you as soon as I can. Lots of rain, huh?? My > > thought ([.......,'. '~~iÀ~~'-"I· .1:1', '11' '>00 ~ 0\tr'~d~~~t;.~) ,j U t ¡~I \J L~i' 1 of 5 2/13/2003 5:33 PM f .. RE: Unocal- Dillon Platform: Di-14 10403 Approval for Diaposal ) ) > > on the pressure value was that disposal would take place as had been > shown > > during the testing. I will have to check on this. I have not done much > > specific work on Di-14 and would need a little time to get all in order. > > With > > regard to pressure, if you increased the rate and the pressure just > > increased > > and held, that is a good thing. Conversely, if you went up on rate and > > the > > pressure increased and then fell, that would not be good and might > > jeopardize > > what you already have with Di-12. I will get back to you as soon as I > > can. > > Tom » > > '~yer, Phil M -Alaska" wrote: » > > > Tom and Bob, > > > We will likely be in need of additional disposal on Dillon if it rains > > again > > > in the next 24 hours or so. Can the 10-403 on Di-14 be approved as Di- > 12 > > may > > > not be able to handle it all. > > > In addition we intend to increase the self imposed injection pressure > > form > > > 1500 psig to 2000 psig immediately > > > Phil »> > > > Phil Ayer > > > Unocal Corporation > > > 909 W. 9th Ave, Anchorage, AK 99515 > > > email: pmayer@unocal.com > > > 907-263-7620 (work) > > > 907-250-2711 (cell) > > > 907-263-7847 (fax) »> > > > -----Original Message----- > > > From: Ayer, Phil M -Alaska > > > Sent: Friday, February 07, 2003 5:47 PM > > > To: 'Tom Maunder'; Crandall, Robert P -AOGCC > > > Cc: Dolan, Jeff J; Myers, Chris S > > > Subject: FW' Unocal- Dillon Platform: Well Disposition Proposal Review »> > > > Informal Meeting to Review Unocal's Proposal for Disposition of Wells > > during > > > Suspension of Operations/Production at Dillon »> > > > Tuesday, 2/11/03 > > > 10:00-11:00 a.m. > > > AOGCC Office, Anchorage, Ca. »> > > > Attendees: > > > Unocal: Phil Ayer, Jeff Dolan, Chris Myers (via conference call) > > > AOGCC: Tom Maunder, Bob Crandall, others as see fit »> > > > Special Requirements: > >. > Conference phone > > > Call to Kenai (907-283-5515) »> > > > Meeting Agenda/Discussion Points '0,r .'~j~ ',N F~_. ~~\...1['\~,~ 1',,', ' .. ~ 20f5 , 1t.? D \Ì .~ '.\ '-.' U'" ~} ".. ~ ~. 2/13/2003 5:33 PM RE: Unocal- Dillon Platform: Di-14 10403 Approval for Diaposal ) ) »> > > > 1. Opening comments - Unocal - 1 minute > > > 2. Background/context of proposal - Unocal -2 minutes > > > 3. Present Unocal's proposal for disposition of wells (shut - in) - 1 > > minute »> > > > 4. Obtain feedback from AOGCC - 30 minutes > > > - On the proposal (i.e. get issues on the table) > > > -Is AOGCC approval necessary to leave wells shut-in? > > > - AOGCC approval process for leaving wells "shut- in" > > > - What are paperwork steps? > > > - Other steps? > > > - Information/justification needs, if any? > > > - 403's vs. no 403's (are they even required) > > > -Estimate of minImax time to gain approval > > > 5. Action plan steps for Unocal and AOGCC to resolve issues - all- 10 > > > minutes > > > - what, who, when »> »> »> > > > > -----Original Message----- > > > > From: Tom Maunder [mailto:tom maunderCëD.admin,state.ak.usl > > > <mailto:{mailto:tom maunderCëD.admin.state.ak.usl> > > > > Sent: Friday, February 07, 2003 10:45 AM > > > > To: Ayer, Phil M -Alaska > > > > Cc: Bob Crandall; John 0 Hartz > > > > Subject: Re: Unocal- Dillon Platform: 10-403 Requirements for Shut- > In > > > > Proposal »» > > > > Hi Phil, > > > > Bob is not here today, but I have checked the calendar and the time > is > > > > presently free. I request that in advance of the meeting you send > in »a > > > > document that outlines the discussion points from Unocal's point of > > view. > > > > When we talked, you mentioned a few of the discussion items (shut- > in > > vs. > > > > suspended), (403s vs. no 403s), (if shut-in, how long before further > > work > > > > is > > > > required). Scheduling this meeting is appropriate to put the > > discussion > > > > items "on the table Fl. The ultimate decision of what mayor may not >be > > > > required will be the Commissioner's and there may be a public > portion > > to > > > > the > > > > process. As you are aware, ONR likely has a role in the process as > > well. > > > > Please call with any questions. > > > > Tom Maunder »» > > > > '~yer, Phil M -Alaska" wrote: »» > > > > > Tom and Bob, sc.£\rðh\EL , 30f5 oi~ ') n \"1:1 V' c..l L...., 2/13/2003 5:33 PM RE: Unocal- Dillon Platform: Oi-14 10403 Approval for Oiaposal ') ) > > > > > How about Tuesday at from 10 to 11 a.m. and we can conference call > > in > > > > > with Chris Myers in Kenai? > > > > > Phil »»> > > > > > Phil Ayer > > > > > Unocal Corporation > > > > > 909 W. 9th Ave, Anchorage, AK 99515 > > > > > email: pmayer@unocal.com<mailto:pmaver@.unocal.com> > > > > > 907-263-7620 (work) > > > > > 907-250-2711 (cell) > > > > > 907-263-7847 (fax) »»> > > > > > -----Original Message----- > > > > > From: Ayer, Phil M -Alaska > > > > > Sent: Thursday, February 06, 2003 5:40 PM > > > > > To: 'Tom Maunder'; Crandall, Robert P -AOGCC > > > > > Cc: Dolan, Jeff J; Myers, Chris S > > > > > Subject: RE: Unocal- Dillon Platform: 10-403 Requirements for > Shut- > > In > > > > > Proposal »»> > > > > > Monday is the only day Chris will be in Anchorage next week. Any > > > > > possibility of squeezing us in 8 a.m. or 3:30 p.m. on Monday for >an > > > > > hour? »»> > > > > > Phil Ayer > > > > > Unocal Corporation > > > > > 909 W. 9th Ave, Anchorage, AK 99515 > > > > > email: pmayer@unocal.com<mailto:/Jmaver@.unocal.com> > > > > > 907-263-7620 (work) > > > > > 907-250-2711 (cell) > > > > > 907-263-7847 (fax) »»> > > > > > -----Original Message----- > > > > > From: Ayer, Phil M -Alaska > > > > > Sent: Thursday, February 06, 2003 5:00 PM > > > > > To: 'Tom Maunder'; Crandall, Robert P -AOGCC > > > > > Cc: Dolan, Jeff J; Myers, Chris S > > > > > Subject: RE: Unocal- Dillon Platform: 10-403 Requirements for > Shut- > > In > > > > > Proposal »»> > > > > > Tom, > > > > > I spoke to Bob Crandall today and he suggested that next Tuesday > > morning > > > > > would be a good time to meet at the AOGCC office to discuss 1) our > > > > > Dillon well plan proposal (suspension vs shut in) and 2) the > > associated > > > > > paperwork (10-403's or not) that might be involved. Please advise >as > > to > > > > > whether this is a good day with you and let's try to pick a time. > I > > > > > envision a 30 minute meeting but we might as well leave 60 minutes > > open, »»> > > > > > Please advise ASAP as I need to give Chris Myers, our field , Î!I\"'-" cú"'" t\ 'II>..~~~t;:.;:..-,' "-J! ~,f h i: ~ ,,:!\ 4of5 ''>0 ~ Df\!' C b ¿ ,VI 2/13/2003 5:33 PM RE: Unocal- Dillon Platform: Di-14 10 403 Approval for Diaposal ') > > > > > superintendent, enough time to plan for trip over form Kenai. »»> > > > > > Thanks »»> > > > > > Phil Ayer > > > > > Unocal Corporation > > > > > 909 W 9th Ave, Anchorage, AK 99515 > > > > > email: pmayer@unocal.com<mailto:omaver@unocal.com> > > > > > 907-263-7620 (work) > > > > > 907-250-2711 (cell) > > > > > 907-263-7847 (fax) »»> > > > > > -----Original Message----- > > > > > From: Ayer, Phil M -Alaska > > > > > Sent: Tuesday, February 04, 2003 8:37 PM > > > > > To: 'Tom Maunder'; Crandall, Robert P -AOGCC > > > > > Cc: Dolan, Jeff J > > > > > Subject: Unocal- Dillon Platform: 10-403 Requirements for Shut-In > > > > > Proposal »»> > > > > > Tom and Bob, > > > > > Paper work question as I am trying to scope action plan for this > > well > > > > > status change work. > > > > > I realize 1 0-403's will be required to be submitted on all Dillon > > wells > > > > > (producers, injectors) if we propose to Suspend the wells. Are 10- > > 403's > > > > > required to be submitted on all wells if we propose to leave them > > > > > shut-in? Or does the shut-in approval from the AOGCC requested > and > > > > > replied to in another way besides the 1 0-403's? »»> > > > > > Phil »»> > > > > > Phil Ayer > > > > > Unocal Corporation > > > > > 909 W. 9th Ave, Anchorage, AK 99515 > > > > > email: pmayer@unocal.com<mailto:omaver@unoca/.com> > > > > > 907-263-7620 (work) > > > > > 907-250-2711 (cell) > > > > > 907-263-7847 (fax) »»> »»> ) ---·---------1 Name: Di-14 Inj Hotsheet 030115.xls o Di-14 Ini Hotsheet 030115,xlsl Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 5 of 5 SCP~NNEL' u Ü 20 [q 2/13/2003 5:33 PM } } Dillon Platform ¡~~ \ \)~N\ Disposal Well Hot Sheet Disposal Well #_14 EJ Meter Daily Cu S SS 133/8" II ~ Hour Reading Rate Injection bg Tbg Csg Barrels Barrels SI PSI PSI PSI Comments 1/14/03 4:00 380 3000 500 500 Start filling hole via LS 1/14/03 4:00 380 3000 500 500 Hole Full. Began injection 72 At Surface 6:00 480 3000 950 950 72 7:00 585 2400 850 850 72 7:30 669 1800 850 850 72 7:45 695 3000 1300 1300 72 8:00 723 2600 1400 1400 72 8:15 758 2600 1350 1350 72 8:30 787 2600 1300 1300 72 8:45 818 2900 1400 1400 72 9:00 861 2600 1400 1400 72 9:15 884 2600 1400 1400 72 9:30 926 2600 1400 1400 72 9:45 954 2500 1450 1450 72 10:00 987 2600 1400 1400 72 10:15 1014 2500 1400 1400 72 10:30 1045 2500 1500 1500 72 10:45 1070 2400 1500 1500 72 11:00 1104 2400 1400 1400 72 11 :15 1130 2300 1400 1400 72 11 :30 1155 2300 1400 1400 72 11 :45 1181 2300 1400 1400 72 1/15/03 12:00 1208 2300 1400 1400 72 12:15 1235 2300 1450 1450 72 12:30 1260 2300 1400 1400 72 12:45 1287 2300 1400 1400 72 1:00 1313 2200 1400 1400 72 1:15 1339 2200 .-"'" 1400 1400 72 1:30 1364 2200 L.~ 1400 1400 72 1:45 1389 2200 1400 1400 72 2:00 1414 2200 1400 1400 72 2:15 1444 2200 1400 1400 72 2:30 1467 2200 1400 1400 72 2:45 1492 2200 1450 1450 72 3:00 1517 2200 1450 1450 72 3:15 1543 2200 1450 1450 72 3:30 1567 2100 1400 1400 72 3:45 1592 2100 1400 1400 72 4:00 1617 2100 1400 1400 72 4:15 1643 2100 1400 1400 72 I I 4:30 1666 2100 1~00 1400 72 I I 4:45 1690 2100 1400 1400 72 I I 5:00 1714 2100 1400 1400 72 I I 5:15 1739 2100 1400 1400 72 I I 5:30 1763 2100 1400 1400 72 5:45 1788 2100 1400 1400 72 6:00 1811 2100 1400 1400 72 I I 7:15 1927 2100 1400 1400 72 I I 7:30 1950 2100 1400 1400 72 I I 7:45 1975 2100 1400 1400 72 I I 8:00 2010 2100 1400 1400 72 9:00 2103 2100 1400 1400 72 10:00 2182 1800 1500 1500 72 11:00 1500 1500 1500 72 12:00 2320 1350 1400 1400 72 13:00 2377 1400 .I (( \ 1400 1400 72 14:35 2479 1400 \~'-J 1400 1400 72 I I 15:00 2511 1400 1400 1400 72 I I 16:30 2600 1400 1400 1400 I- 72 . I I 17:00 2634 1400 1400 1400 72 I I 17:15 2650 1400 1400 1400 72 At Surface 17:17 0 0 0 0 Stop injection. Press to zero instantly. 2/13/2003 5:33 PM Di-14 Inj Hotsheet 030115.xls Di-14 Inj Hotsheet 030115.xls Test Sep. Well Test SCl\NNEL\ ,Jut ø f.þ 200,1· #10 ) ') Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7805 RECE~V7E[) UNOCALe "I","i!l'~ Alaska JAN 2 4 '2003 Naska Œ~ & Gas Cons. Cm'11misslorr: Äf!!chora!lE; January 23, 2003 State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Attn: Tom Maunder Dillon Application for Temporary Disposal Well Di-12, Di-14 Dear Robert Crandall: Union Oil Company of California, d.b.a. Unocal, requests that Rule # 9 under Area Injection Order # 8 be used to provide the administrative relief clause to authorize temporary disposal in the Hemlock zones of the South Middle Ground Shoal Field. Please find enclosed forms 10-403 for wells Di-12 and Di-14 and additional supportive information requesting permission for temporary disposal. It is our intent to dispose exclusively in to de-commissioned injection well Di-12 (that has been shut-in since 1986) and use Di-14 (a depleted producer) as a back-up. We are anticipating disposal of up to 50,000 barrels of fluid. If you have any questions regarding this, please contact me at 263-7620. S~M"~ Philip M. Ayer Advising Petroleum Engineer Enclosures Aogcc SMGS Dillon - Application for temporary disposal 030l23.doc ~(;!\NNEC' JUt 0 6, ZDOl} jjd ) Unocal Alaska Dillon Platform Proposal for Fluid Disposal January 23, 2003 Proposal Unocal requests that the AOGCC provide authorization for utilizing existing injection and or production wells currently approved for EOR operations in the South Middle Ground Shoals Field (Platform. Dillon) Pools G for temporary disposal of approximately 50,000 barrels of non-hazardous oil field fluids. Proposal Context The South Middle Ground Shoals field has reached its economic limit and is depleted. Oil production from the Dillon Platform. was shut in on December 8. It is Unocal's intention to clean the surface equipment from January through April 2003 and lighthouse the facility by July 2003. One of our primary concerns is the disposal of the clean up fluids in an appropriate and economic fashion. Finalizing our plans is dependent upon the method for disposal of fluids. We are requesting your review, support, and approval of our plans to inject into the current EOR zone. A number of wells have been identified as candidates for disposal injection of which two are being proposed at this time; Di-12 as the primary disposal well and Di-14 as a back up. Having a backup disposal well is considered important insurance for success. Although neither of these wells has passed a Standard MIT, alternate methods (pressure diagnostics, injectivity tests followed by static temperature surveys) were used to demonstrate the fluid was entering the intended injection zones. Field Historv The South Middle Ground Shoal Field encompasses the southern nose of the Middle Ground Shoal structure. This portion of the field was proved in October of 1965, when the Chakachatna group tested 2,130 BOPD from a lower Tyonek conglomerate in an expendable well. Platform. Dillon was installed in 1967. Waterflood operations were initiated in 1969 and were suspended in 1986. The platform. was shut down in 1992 and 1993 due to low oil prices. All wells are completed in the "G ''unit of the lower Tyonek. Gross platform. production in October 2002 averaged 449 BOPD, 4045 BWPD, and 236 MCF/d (see production curve attached). Prior to shut down of production on December 8, there were eight active producing wells, four shut-in producers, and five shut-in injectors. Reservoir Depletion The OOIP within the G sands in the developed portion of the South Middle Ground Shoal Field is 120 MMSTB. Cumulative production as of October 2002 is 28.1 MMSTB which represents a recovery of23.2 % of the OOIP and 43.8 % of the MOIP (moveable oil in place) in the developed area. The MOIP is calculated assuming an initial oil saturation of Dillon Platform Proposal for Fluid Disposal Page I of 5 1/23/2003 ~.......~...,¡\ \1<..n\~E·::LI' ~l· ij~i. 0 G 20Dl}. 1; '~\,þ ,.,".~.~'1j~,~ '\;.!» L. ) ') 60 % and a residual oil saturation of28.2 %. Producing water cuts have been approximately 90 % since 1983 except for four years from 1994-1998 when the impact of a few development wells was seen. Current reservoir pressure within the "G" sands is 2224 psig @ adjusted to a 8500 ss ft datum as compared to the original pressure of 4220 psig @ same datum (Middle Ground Shoal Field). The current pressure is estimated from shut-in fluid level shots from 12/12/02 thru 12/18/02 on Di-14, Di-17, Di-2rd, Di-12, and Di-16 adjusted to the 8500 ss ft datum. Although the field was being produced by volumetric expansion, the last producing GOR was only 429 SCF/STB since the reservoir pressure had not dropped below the bubble point pressure of 1500 PSIG. Cleaning and Disposal Operation Up to 50,000 barrels of Class II non-hazardous fluid, heated to approximately 70 degrees Fahrenheit, will be disposed during the clean up operations. This fluid will be comprised of unfiltered inlet water, produced water, produced oil, sludge, triethyleneglycol, paraffin and asphaltenes. Daytime clean up activities should continue over the next six month period and are expected to generate 80 to 300 barells of fluids/solids daily. The daily disposal amount is dependent on the size of the vessel being cleaned. At average estimated injection rates of 1000 BWPD (roughly 0.7 BPM) at 3500 psig, the daily time to inject would range from 2.5 to 8 hrs. If rates are less, say 0.25 BPM, the time to inject would range from 8 to 24 hrs. Actual disposal injection pressures and rates will likely be less than injection rates fifteen years ago but at that time the Dillon injection wells ranged from 500 to 2100 BWPD/well at pressures ranging from 3100 to 4000 psig. Parting pressures (frac pressures) determined at that time in injection wells Di-12 and Di-ll were 4100 and 4800+ psig respectively. It is not expected but if fracing is necessary during disposal, pump pressures approaching 5000 psig would be needed. Formation Integrity Tests Typically when Unocal sets a string of casing, a formation integrity test, or "leak-off test" is performed to measure the ability of the casing, cement and formation to withstand pressure during a blowout or kick. No formation integrity tests were performed on the various casing shoes in Dillon # 14, as this was not the original operator's practice at that time. However, in 1994, Unocal drilled and completed three wells at Dillon, including Dillon # 17. The following table summarizes the results, showing the maximum pressure the well was subjected to without fracturing: WELL CASING EQUIV ALENT PRESSRUE PSI DEPTH, MUD WEIGHT GRADIENT, (TVD) (#/GAL) (PSI/FT) DILLON #16 1133 18.1 0.941 1066 3640 15 0.780 2839 9470 14.1 0.733 6943 DILLON #17 1133 16.5 0.858 972 Dillon Platform Proposal for Fluid Disposal Page 2 of 5 e:::'. ((··J\i~~\>ì..eE~··rl' . r,\ì (~ [; f~ r)oo,q û'b+'ffi,B'ìjß''J l..' IlLn 'J..I u (." ,,-J' '" "1123/2003 ) ) 3548 14 0.728 2583 9200 16.5 0.858 7894 DILLON #18 1133 15.9 0.827 937 3988 14.6 0.759 3028 9450 15.3 0.796 7518 One can see from the data that the formation at Dillon is very competent, especially near the surface, where the fracture gradient exceeds 0.827 psi/ft. Therefore, the proposed injection wells should be more than capable of withstanding injection pressures in the range we expect. l",;hH~; r[ \! (, U 2004 Dillon Platfonn Proposal for Fluid Disposal Page 3 of5 1/23/2003 ) ) Dillon 14 - Disposal Well Candidate Disposal Fluid Area of Influence Disposing of 50,000 barells of fluid will radiate only 117 feet from the wellbore or 1.0 acres total. History Dillon # 14 was completed as an oil well in 1976 in the Gl, G2, G3b, and G4 sands. As of October 2002 the well was on hydraulic lift (KOBE pump) producing 808/59 B/D, 93 % cut, 500 GOR. The well was shut in on December 8, 2002. See well schematic, production curve, and well log attached Vert. Net Pay = 138' (assumed = to feet of perforations since nearly vertical across zone) Porosity = 18 % Swi= 50% Depletion Assessment Cumulative production as of October 2002 is 2.0 MMSTB. Assuming a recovery efficiency of23.2 % of the OOIP (which is the field wide average), the well has drained 53% of the MOIP (moveable oil in place) over 108 acres (1225 ft radius). MOIP calculated assuming an initial oil saturation of 50% and a residual oil saturation of 28.2 %. Producing water cuts have been above 90 % since 1994 and gradually increasing. Current reservoir pressure in the well is 2691 psig @ top perforation (9205 ss feet) as compared to the original completion pressure of3636 psig(datum unknown but assumed to be at top perf). The current pressure is estimated from a shut-in fluid level shot on 12/16/02. A static pressure survey run on 12/17/02 confirmed the fluid level estimated reservoir pressure. Because the reservoir is depleted it is anticipated that the injection pressure in this well will be relatively low. Mechanical Integritv History The well is completed with a 3 ~ tubing string set in a 7" permanent packer at 9547' (refer to attached diagram). A 67' short string was run to receive produced fluids coming up the 9 5/8" x 7" production casing/liner. The individual casing and liner strings were pressured tested upon initial installation. No casing or tubing inspection logs have been run since the well was drilled in 1976. There are no indications that any of the casing strings have problems or leaks. ~iC;t-\NNEli JUt. 0 Œ) 2DD,} Dillon Platform Proposal for Fluid Disposal Page 4 of 5 1/23/2003 ') ) The 9 5/8" intennediate/production casing was cemented at 9624' on 2/5/76 with 950 sx of class 'G' cement mixed at 15.8 ppg. Good circulation was observed throughout the job, but no CBL was run on the 9 5/8" casing. The calculated cement top is at approximately 6000'. The likelihood of channeling around good cement between 9624' and 6000' is very low. The 7" liner was cemented at 10,500' on 2/21/76 with 750 sx of class 'G' mixed at 15.8 ppg. Full returns were observed throughout the job. A cement bond log was run throughout the 7" liner, from 10,463' up to 9300', on 2/23/76. The log indicates an excellent cement bond throughout the liner. The 3/1/2" tubing currently in the well was run on 418/85. The well was recently producing with a KOBE pump, and the power fluid was pumped down the tubing with a surface pressure of 3000 psi. The high pump efficiency on the well indicates the tubing was mechanically sound. A Bundle (i.e. jug) MIT was attempted on Di-14 on 12/23/02 without successful results (the test lasted less then 30 seconds). Analysis of the bundle test indicates the tubing likely failed just below the standing valve during the test. On 1/10103, conversations with the AOGCC confinned that mechanical integrity could be obtained for a well that failed a pressure MIT if it could be proven by another means. One method, an injectivity test followed by a static temperature survey (that indicates no fluid exiting the casing) was deemed an acceptable method. A 24 hour injectivity test was perfonned on this well on 1/14-15/03 followed by two static temp surveys. A total of2500 bbls of72 degree water was injected at rates ranging from 2500 to 1500 bid at pressures not exceeding 1500 psig. Analysis of the temperature surveys, along with the baseline temp survey run on 12/17/02, indicate the casing in this well is not leaking and all fluid is exiting the intended zones. During disposal operations, it is intended to heat disposal fluids to approximately 70°F to minimize the unlikely possibility of excessive tubing shrinkage or parting of the tubing. Well Observations Pertinent to Mechanical Integrity: · Well Service Reports identify no substantial problems in entering tubulars. · There is no fill covering the perforated interval. Small fish below perforations. · While producing, hydraulic lift system was injecting power fluid down tubing at 3000 psig and producing the well up the casing annulus at 90 psig. This consistent 2900 psig differential along with high pump efficiencies indicated tubing mechanical integrity and likely casing mechanical integrity. Dillon Disposal to AOGCC 030123.doc .~3(;"~\NNE~.1 JUt (J ö ?OD,~~ Dillon Platform Proposal for Fluid Disposal Page 5 of 5 1/23/2003 DillON Platform Cumulative Gas Prod: 10255 MMcf 28081 Mbbi 100 10 80 8 60 6 40 4 20 2 0 0 196 105 10° TIm ·--·è-· ¡ i i ¡ ¡ í ¡ ¡ I : , , ¡ , i :- . i ! ! r ¡ ! ¡ II ! r~ Oii Rate (CD) ( bblld ) ,:ate .... Liquid Rate (CD) ( bbl/d ) , , , , Water Rate (CD) ( bbi/d ) t::i':Iol Rate (~D) : 5 ~ Mef, rd OURate:(Cp) " 2~!2hhIJti Gas I Oil Ratio ( cf/bbi ) : ,: ¡ Cut. 66,S ð' : Water inj Rate (CD) ( bbl/d ) ."""" .,... InjRælte eCI) : 3 ....n·... , , 1965 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 7000 01 02 4 10 103 102 1 10 -1 10 PMA B General Platform Wtrfld Prod Plot01/23/03 15:25:24 22aooo 2"6OØO + 611'48'/1 2"4ÐOO 2"aooo + . . 2_ + . 2476000 ,(/',,1'/1 + 2474000 + 2472GOO 24100a0 + + 247??oo '(/'4$'/1 '(/,4$'H 2'_ + 24_ 2'_ + 24e6OØO 2._ + + -- '(/'44'/1 '(/'4"'/1 2<_ + 241aooo 2<_ + 2<_ 2<_ + 2_ '. '(/,"3'H '. '(/'43'H 2<56OØO + 2456OØO 245<_ 2<5aooo 22aooo 224C1OO o 1000 2000 h . , SCALE IN FEET '$,032'1'6OØO 221000 1S°:Jø,~33000 4000 I + 24$4000 2453000 2_ 23SOOO 231000 ...... ..._ ........ ØI . C. ..... a.I~~r.... DILLON PLA TFORM TOP HEMLOCK STRUCTURE -..- .... SttOMI ...,...!ANNØt :.. JrIIW. 10. ,... , . . MIDDLE GROUND SHOAL TOP HEMLOCK STRUCTURE DILLON PLATFORM IN SUPPORT OF AFE-741501 L_ AREA OF WATER FLOOD '. . .) '.. I I I I I I I I I I I I I I I I I I I '------ '. ........ ..--- ,------, I I' I, IG-4 I I I I I I --' I I I I I I I WEST FORELAND _ __________J. 2000 FEET '. ' ------------- SMGS UNIT WELL 13 f'-.. ~ H I L W I '" Z D ~ ~ I---f H '" (/) LJ L '" ~ (/) W ~ I---f LL '" @ . . ;' - .":-~ i_ ..) '.~ .. MIDDLE GROUND SHOAL DillON PLATFORM A sw ..- ZONE 1 --5000' - 7-0~'é. 3 -7000' - 7-0~~ 4 '. " -9000' - W. FORELAND PRE-TERTIARY -11,000' - 2000 FEET A' NE C) .~ "'C . Q) "'C .- - U> I'- ,.. "'C -....... E o o .. co ..... co "'C -....... tJ) (I) - .- 'I- ......... [Fwd: Unocal Dillon - D-12 Injectivity Test and MI Request] . ~ ~ . Subject: [Fwd: Unocal Dillon - D-12 Injectivity Test and MI Request] Date: Fri, 17 Jan 2003 08:07:57 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Daniel T Seamount JR <dan_seamount@admin.state.ak.us>, Mike Bill <mike_bill@admin.state.ak.us>, Cammy Oechsli <CammLOechsli@admin.state.ak.us>, Jim Regg <jim_regg@admin.state.ak.us>, Bob Crandall <bob_crandall@admin.state.ak.us>, John D Hartz <jack_hartz@admin.state.ak.us> All, Enclosed is the latest message from Phil Ayer at Unocal. He has kept searching for a well that might meet the necessary criteria and he may have found one. Di-12 is an injector and it appears that they may have demonstrated MI. He has performed an injectivity test and from the information he has provided, it appears that this well has passed a MIT. Their rate was about .75 bpm and he indicates that there was 0 pressure on the IA. Demonstrating MI via observation is acceptable and I can support acceptance of this information. What are your thoughts?? I indicated to Phil in a message that this information was encouraging and that I would forward it on. One remaining task we would have would be to do the file review. Any comments and suggestions would be appreciat~d. Tom Subject: Unocal Dillon - D-12 Injectivity Test and MI Request Date: Thu, 16 Jan 2003 20:53:46 -0800 From: "Ayer, Phil M -Alaska" <pmayer@unocal.com> To: "tom_maunder@admin.state.ak.us" <'tom_maunder@admin.state.ak.us'>, "winton _ aubert@admin.state.ak.us" <'winton_ aubert@admin.state.ak.us'> CC: "Dolan, Jeff J" <dolanjj@unocal.com> Tom An injectivity test is currently being performed on Di-12. Injection began at 10:00 p.m. on 1/15/03. A total of 370 bbls of 72 degree water has been injected as of 1 :00 p.m. today. Injection rates down the LS have been in the range of 950 bId at 1400 psig with ~on the casing/tubing annulus. The well is indicating that tubing/packer mechanical integrity exists as there is a 1400 psig differential between the tubing and the annulus with no indication of flow. Unocal requests MIT approval on this well based on the injectivity data attached. If needed, we intended to follow the injectivity test with static temp survey(s) but since the well is indicating pressure integrity we question whether the temperature surveys are needed. There is a real risk of sticking the temp tools in this shut-in injector so if it is not necessary we would rather not run them. In addition a w/I gauge run on 1/4/03 could not progress beyond 5,129' and this may preclude a survey form beyond this point. If on the other hand we need the temp surveys, the time to run them is immediately after the injectivity test which should end tomorrow evening. Your prompt review of this matter is requested. I will call tomorrow to discuss. Thank you. Phil Phil Ayer Unocal Corporation 909 W. 9th Ave, Anchorage, AK 99515 email: pmayer@unocal.com 907-263-7620 (work) 1 of 2 1/28/200310:21 AM [Fwd: Unocal Dillon - D-12 Injectivity Test and MI Request] ,. 4IÞ 4IÞ 907-250-2711 (cell) 907-263-7847 (fax) ......,,,,,-""',,.._:.:...........=........""".,...,"........,..,-,......,....,..,.....,, Name: Well #12 Hot Sheet.xls DWell #12 Hot Sheet.xls T~pe: Microsoft Excel Worksheet (application/vnd.ms-excel) Encodmg: base64 Description: Well #12 Hot Sheet.xls Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2of2 1/28/200310:21 AM . . Dillon Platform Welllnjectivity Test Date 1/15/03 -1/16/03 Well #_12 BB Meter Daily long Short 95/8" D Injection Csg Reading Rate String String Annulus Wtr Fluid Barrels PSI PSI PSI TemD. level I 1/15/03 I 10:00 0 0 o Start filling up LS 72 4002 11:00 80 0 Long string full 80 bbls 11:00 0 1450 Zero'd meter. Began Injection 72 11 :15 22 1000 1450 0 72 I I 11 :30 33 950 1450 0 72 11 :45 43 950 1400 0 72 1/16/ 12:00 53 950 1400 0 72 12:15 63 950 1400 0 72 12:30 73 950 1400 0 72 12:45 83 950 1400 0 72 1:00 92 950 1350 0 72 1 :15 102 950 1400 0 72 1 :30 112 950 1400 0 72 1:45 122 950 1400 0 72 2:00 132 950 1400 0 72 2:15 142 950 1400 0 72 I I 2:30 152 950 1400 0 72 I I 2:45 162 950 1400 0 72 I I 3:00 172 950 1400 0 72 4002 I I 3:15 182 950 1400 0 72 3:30 191 950 1400 0 72 3:45 201 950 1400 0 72 4:00 211 950 1400 0 72 4:15 221 950 1400 0 72 4:30 231 950 1400 0 72 4:45 241 950 1400 0 72 5:00 251 950 1400 0 72 5:15 261 950 1400 0 72 I I 5:30 271 950 1400 0 72 6:30 308 900 1400 0 72 7:30 332 900 1200 0 72 8:30 370 900 1400 o SID to access TK # 5 72 I I 12:30 370 0 0 0 72 I I 12:45 Start fill LS 72 1:00 1250 LS full. Resume injection. 72 2:00 72 1/28/2003 10:21 AM Well #12 Hot Sheet1.xls Well #12 Hot Sheet1.xls Test Sep. Well Test 3000 4000 7000 9000 10000 11 000 o N me ~ Oi - J 2 ELEV~ KB 11000 FEE1 We 1 10000 DillON Platform Cumulative Gas Prod: 73 MMcl 30 1.0 0.4 25 ater Cut ( % ) Is on Gas Production 115 on Oil Production lis 011 Water Injection 0.6 0.8 20 15 0.2 10 5 0.0 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 2000 01 1968 69 70 71 72 73 74 75 5000 ~~- .~\.f- H ji tf ¡'It' ¡y¿Ji I I ¡I' I \ - _J .~~~ -- , ¡ \ \ ._-- ::~: O¡ Rate (CD) ( bblld ) ... .L. I: -..... "'.... ,^ .--. .--. liquid Rate (CD) (bblld) ............, ,...",.. ..... ,... Water Rate (CD) (bbl/d ) Ui:i5 Rate (CD: : 149 Mcf/d ' OitR~te (CD) ,447uUI/Ù Gas I Oil Ratio ( cl/bbl ) . '. ¡ ; , !;PI.. i ---- Water Inj Rate (CD) ( bblld ) . , , ". ..........I~lRate (qD) bbl, ¡ , , , 1968 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 98 99 2000 01 02 1000 500 100 50 10 PMA B General Platform Wtrfld Prod Plot01/23/03 15:28:57 -- e Phil M -Alaska From: Ayer, Phil M -Alaska Sent: Friday, January 17, 2003 12:06 PM To: 'Tom Maunder' Cc: Dolan, Jeff J Subject: RE: Unocal Dillon - D-12 Injectivity Test and MI Request Tom Page 1 of2 The injectivity test on Di-12 is scheduled to end by 3 p.m. today. Injection began at 10:00 p.m. on 1/15/03. A total of 1339 bbls of 72 degree water has been injected as of 11 :00 a.m. today. Injection rates down the LS are currently in the range of 950 bId at 1450 psig with ~on the casing/tubing annulus. The well is indicating that tubing/packer mechanical integrity exists as there is a 1450 psig differential between the tubing and the annulus. Unocal requests MIT approval on this well based on the injectivity data previously submitted. As mentioned in the previous email, we intend to follow the injectivity test with static temp survey(s) but since the well is indicating adequate pressure integrity we question whether the temperature surveys are needed. There is a real risk of sticking the temp tools in this shut-in injector so if it is not necessary we would rather not run them. In addition a w/I gauge run on 1/4/03 could not progress beyond 5,129' and this may preclude a survey form beyond this point. If on the other hand we need the temp surveys, the time to run them is immediately after the injectivity test which should be at 3 p.m. Your prompt review of this matter is requested. There is no CBL on this well. I will be bringing over the CBL and temp surveys on Di-14 after lunch. Perhaps we can discuss further in person at that time. Thank you. Phil Phil Ayer Unocal Corporation 909 W. 9th Ave, Anchorage, AK 99515 email: pmayer@unocal.com 907-263-7620 (work) 907-250-2711 (cell) 907-263-7847 (fax) -----Original Message----- From: Tom Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, January 17, 2003 8:03 AM To: Ayer, Phil M -Alaska Cc: Jeff Dolan Subject: Re: Unocal Dillon - D-12 Injectivity Test and MI Request 1117/2003 20 - e Page 2 of2 Phil, This is encouraging information. Was this the well that you tried to get into with wirelne? I have not looked at any information from the file on this one. Is there any bond log out there?? I will forward this information on to the other staff. Torn Maunder "Ayer, Phil M -Alaska" wrote: Tom An injectivity test is currently being performed on Di-12. Injection began at 10:00 p.m. on 1/15/03. A total of 370 bbls of 72 degree water has been injected as of 1 :00 p.m. today. Injection rates down the LS have been in the range of 950 bId at 1400 psig with ~on the casing/tubing annulus. The well is indicating that tubing/packer mechanical integrity exists as there is a 1400 psig differential between the tubing and the annulus with no indication of flow. Unocal requests MIT approval on this well based on the injectivity data attached. If needed, we intended to follow the injectivity test with static temp survey(s) but since the well is indicating pressure integrity we question whether the temperature surveys are needed. There is a real risk of sticking the temp tools in this shut-in injector so if it is not necessary we would rather not run them. In addition a w/I gauge run on 1/4/03 could not progress beyond 5,129' and this may preclude a survey form beyond this point. If on the other hand we need the temp surveys, the time to run them is immediately after the injectivity test which should end tomorrow evening. Your prompt review of this matter is requested. I will call tomorrow to discuss. Thank you. PhilPhil Ayer 11¢'"~ ~." Unocal Corporation 909 W. 9th Ave, Anchorage, AK99515 email: pmayer@unocal.com 907 -263-7620 (work) 907-250-2711 (cell) 907-263-7847 (fax) {i¡,j 1/17/2003 e e Page 1 of 1 Ayer, Phil M -Alaska From: Ayer, Phil M -Alaska Sent: Thursday, January 16, 2003 7:12 PM To: 'tom_maunder@admin.state.ak. us'; 'winton_aubert@admin.state.ak.us' Cc: Dolan, Jeff J Subject: Unocal Dillon - D-12 Injectivity Test and MI Request Tom An injectivity test is currently being performed on Di-12. Injection began at 10:00 p.m. on 1/15/03. A total of 370 bbls of72 degree water has been injected as of 1 :00 p.m. today. Injection rates down the LS have been in the range of 950 bId at 1400 psig with º Q§.ÌfLon the casing/tubing annulus. The well is indicating that tubing/packer mechanical integrity exists as there is a 1400 psig differential between the tubing and the annulus with no indication of flow. Unocal requests MIT approval on this well based on the injectivity data attached. If needed, we intended to follow the injectivity test with static temp survey(s) but since the well is indicating pressure integrity we question whether the temperature surveys are needed. There is a real risk of sticking the temp tools in this shut-in injector so if it is not necessary we would rather not run them. In addition a w/I gauge run on 1/4/03 could not progress beyond 5,129' and this may preclude a survey form beyond this point. If on the other hand we need the temp surveys, the time to run them is immediately after the injectivity test which should end tomorrow evening. Your prompt review of this matter is requested. I will call tomorrow to discuss. Thank you. Phil Phil Ayer Unocal Corporation 909 W. 9th Ave, Anchorage, AK 99515 email: pmayer@unocal.com 907-263-7620 (work) 907-250-2711 (cell) 907-263-7847 (fax) 1/16/2003 e e Dillon Platform Welllnjectivity Test Well #_12 Meter Daily Long Short 95/8" Injection Csg Date Hour Reading Rate String String Annulus Wtr Fluid Barrels PSI PSI PSI TemD. Level 10:00 0 0 o Start filling up LS 72 4002 11:00 80 0 Long string full 80 bbls 11:00 0 1450 Zero'd meter. Began Injection 72 11:15 22 1000 1450 0 72 11:30 33 950 1450 0 72 11:45 43 950 1400 0 72 12:00 53 950 1400 0 72 12:15 63 950 1400 0 72 12:30 73 950 1400 0 72 12:45 83 950 1400 0 72 1:00 92 950 1350 0 72 1 :15 102 950 1400 0 72 1:30 112 950 1400 0 72 1:45 122 950 1400 0 72 2:00 132 950 1400 0 72 2:15 142 950 1400 0 72 2:30 152 950 1400 0 72 2:45 162 950 1400 0 72 3:00 172 950 1400 0 72 4002 3:15 182 950 1400 0 72 3:30 191 950 1400 0 72 3:45 201 950 1400 0 72 4:00 211 950 1400 0 72 4:15 221 950 1400 0 72 4:30 231 950 1400 0 72 4:45 241 950 1400 0 72 5:00 251 950 1400 0 72 5:15 261 950 1400 0 72 5:30 271 950 1400 0 72 6:30 308 900 1400 0 72 7:30 332 900 1200 0 72 8:30 370 900 1400 o SID to access TK # 5 72 12:30 370 0 0 0 72 12:45 Start fill LS 72 I I 1:00 1250 LS full. Resume injection. 72 2:00 I 72 I ,iUL U \) 1/16/2003 7:22 PM C:\Documents and Settings\o2562pma\Local Settings\Temporary Internet Files\OLK34\Well #12 Hot Sheet2.xls Well #12 Hot Sheet2.xls Test Sep. Well Test t'NtIM(lt ""Wi Sþud Dml $lM1ø~ Lqljjriøn¡ Bubtul'f1lH L.ädtlån~ fol-vvdoft! TOI ""1;1: Cã.r"9: SOU'n1 MIDDL~ GROUND ~HO.4,L AbL, 1 8746 W~LL NO, 12 BEMLOCI< CO"l()LOMF,~TE: ÞLATFORIJ DILLON ~8,188 a...1I if !Iãt 8 flToJ' nil.,. 1 '8J.~' f'W(. !¡¡a. :";, ~, In~. 5.11. fØ . I~t I'D.. 11;'1' 1'1i1.. 3'11I0. J, T'1N. R1 J\V. .!.iI. 1.(1" KB ,2000' 'MIlO.." ... . n~" l'KI .4~· " "I', ~,~, CG.1n.J Nt ot U87' ~th 17!ð ." a..".,t i ,\IaH. -4( and 4J';, N-!I[J dnd ~1I:5 C."n, _t Irt , ð~.· with 10110 n NIMfJ" 7'" 2~ an4 21' 3..9' UNr Nl !!It 1fJi7.....11':I)· VIIVI 380 Iix IIrMnt ;~:""'\' ,';""'1.1 11//0' . ~",. Pvffilrtltlm.: 0-,; , 08~-1 fI!l'40- , " 0-2; , 011 :5~'1 fllatJ' 'I,~ 1 D9BJ-1 tlt!!- cr"': , H.l50-11Mð'· , t 076..1 ,08'-. j .,. 1 , HJ2... ~ 12.7:\" '.' r.¡...4! 113å~ fI ~ilØ" r'! :. 1 'I40S-, 1 ..~' lI1ftl.:l1 P6t.-r1tt/llJi Initial 8Umlllg\'lo,u .It~1r Data~ 01 CII1'64 Il'It4lPAlr.. DST 1*tiIlNGI. nnrl ""...b: !.b9 Invantill"y! <!tBn.m; SqlNt!.d as, BOPD, :!I~111WÎ'"D. 24& ur~ ;.;~ Nl!Iont ....--'" ~--- ~6ftlli ,':'--j s-..,..) .~-::> '3dflft. ,.,....,") 1E't.'-$JI'. I!IHC-·QR. '" t 2/24,/68, ~ 4V24' ID. tratti'-~"' ~Qltl! traM...._Mf '/11//:!. tr'aoIr-l.tBnf-atuni 1't11¡f3, trGMr-MmpiratllN 14'311/74_ It'. hDlr prefIJ. fVl.2/T1, 10¡11nt+ )¡2IV$.)f 'II;),!!! f OD~3' ,ooJ4- '0046- '0041- Øo~r UGh! "',·1 fIIu' III/B" ÞorIIi IIliIktlr ~tlaI 1U-r .tDbbld' , \t11Du,h plu' Þut It~t a"WQh,d 10 (n.... ~v. ~n'lPIM'lalt RIIi~~~_ UaR'f 5tr111t,1 I, (:!1IIIJ1I1'V1t 1 DA Nom Duel tubIng hl¡lIrr 2. .:i 117" But.tfoåa \Uþlltt pup ;t. 3 Iii" ButlHlu tultlft. W/AB 1p1ii.1",- i. " 'itA ButtR.. ....11 2 7,"B" ~. ~O I:, 2 1101' Bultra. tuÞtnt pLlp G., 8aIo:tr P41rQnllll ftowhMd I M!I" ad 't_ 2 710M iuttreu tr,¡Þlnp 'liAS t3II.Ipllnp a. 2 "1(fJ" III~I' pup It. t. 2 .,¡'It! tJ¡¡¡~.r 'P nlpp1' 2.2~ lilt '0. 2 718H l:tt,ttNn an~ ,;, ".2" BuU,.... XC , " S.aI IDaator , 2" 9aar aQ4ImÞIy , ~, Bull nlilM IhtlU' ÇIIi~ IIJb ~hol1i $trlrtii Å.. J '/í"' ill~~'1 b.ibtng w/AB oe:6ùþl~iI. ii, 3 112" tlu~,..,. and ~ ',,'8- ButWfl XO t. 2 i/B" fll~...t' P'!P Jt, u. 8ãk...:2 'I"" R-Nlppr. :M 117 Jd. Q. '!'un It"\ '/I&i) I.:t I. &II'·~.'''J'''( III';" ....1.~~7,.1''¡.'' 7', t.,,, ,:ì ~. ,< ...., It;.", 7 2 J ^ I)~ij, ~;S' ~,.' 100~,' 1 00.)" f 004ð' 1004'1' 11 06~' 11 Oet' , , D70' ',071- t f 072- "09;]- '\t QIII4' 13 ;vi' :s..~ CSA1yr e '11 7" 23 81 at, 1.fF!.... ttp at 10t74' v ::va- 4C"J 43.!f ~ 10~1J' DI!!I2!..J1œ4ò. '01115- 11);", " OlD' 11001' frElD "92;)' 1D I 7D)(1' ·~':'\, ",:..t".- ,"".' . ,! e e Unocal Corporation 909 West 911I Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCALe December 11, 2001 , ~. '.' .... ......;.'- ..... '.1' . Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99~O 1-3539 :Q.e: Modified MIT on Dillon 12 Shut-in Injection well Dear Tom: A consecutive, seven (7) day pressure surveillance was finished on the Dillon 12 shut-in injector (Permit # 1680560 API 733-20126-00) on 05/10/01. The tubing, production casing and outer casing pressures were monitored and recorded for three (3) consecutive days. The production casing pressure was altered by 200 psi. Pressures were then monitored and recorded for an additional four (4) consecutive days. See attached data sheet and well schematic. The pressure surveillance data indicates a minor tubing / casing communication but since the 9 5/8 casing is holding @45 psi. with the tubing at zero or on vacuum, Dillon 12 cannot flow from the productive interval into the 9 5/8" caSing. The water flood system on the Dillon Platform has been disassembled and we are not currently planning to resume further injection on this platform. Therefore we ask that you approve the shut-in MIT for the well. Attachments: 10-403 Pressure Test Results Wellbore Schematic Sincerely, (J¡/tI;L- Christopher A. Ruff Senior Reservoir Engineer Cook Inlet Waterflood Management RECEIVED , . '--', f' ..,..--.....~. \'..' : .'- _.. ~_..... ~ ¡ i DEC 3 1 2001 ,<!\Iaska ou & G$ Cons. Ccmmi&~¡{¡í1 Anchorage Aogcc Di 12 SI MIT 12-11-01.doc ¡'ì f! 'I \) JID ,. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS e e '1f¡) I/~)?lti.t " ;1. Type of Request: Suspend: Operation shutdown: Re-enter suspended well: RepåirWell Plugging: -Time extension Stlmulãiã:" Pull tub!n : Variãñce: Perforãtë:" Other: š'i1ut-ln MIT 6. Type of well 6. Datum elevation ( F or KB nocal' Development 110' KB ABOVE MSL feet Exploratory - 7. Unit or Property namE r ~:''',. ',' --'''ii,''';''';'',-,'-'' "' , ~ .. $tratlgraphlc:, - PO BOX 190247 ANC AK. 9951. .~. Service: X South MIddle Ground Shoal 4, Location of well at surfacl Leg 4, '-';~.. .. Platform 8, Well number 673' FSL, 1763' FWL, Sec. 35-T8N-IíI~W-SN No. 12 At top of productive InteM 9. Permit numbe, 68-56 At effective deptl' 10. API number 50-733-20126-00 At total deptl' 11, Field/Poo Middle Ground Shoal/"G" 12, Present well condition summar Total depth: measured true vertlca 1,5ar 12,000' feet Plugs (measured: 10,461' feet 11,923' feet Junk (measured: 9,443' feet Size Cementec 13-318· 1770 Sx 9-51a· 1,060 Sx None Effective depth: measured . true vertlca None Casing Structural Conductor Surface Intermediate Production Uner Perforation depth Length Measured deptl' True vertical deptl' 1,5ar 10,439' 10,439' measured (See Attached Wellbore Schematic; true vertlca Tubing (size. grade, and measured deptl' (See Attached WeUbore SchemaUc; Packers and SSSV (type and measured deptl' BakerMod. 'F1' Packer @ 10,174 13. Attachemente Description summary of proposal .!... Detailed operations prograrr BOP sketch: 14. Estimated date for commencing operatio 16, If proposal well verbally'approvel 16, Status of well classification as . ,. ' 011:_ Gas: SusPended: _ Date. a råved Service X rue and correct to the best of my knowled( Title: Senior Reservoir En Inee Date: 12/2012001 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval Nq~O . J . Plug integrity_ BOP TesL- location clearance_ ::.J . Ið S'\ Mechanicallntegrity Te~~~ Subsequent form required 10- "ð""-<l: C"\.. ~\ ... ~r~ \ ~....\~~,\,,~ o~ Ç>~~~~~~~o..~~~~~\\c:o«JI:~r-... \'I> ~ ~~ Approved by order of the Commissioner Cä Cover Jetter at\\Ak-Anchorage\Groups\AOGCC\Corres ondences\Aogcc Di 12 SI MIT t~""l t,o'1~d~:"",,, ¡¡;. {'V"'" :~'''''\, YY'\t:. \.,¡ t: I '~i ï: u Commissioner ~ Date .> 2 1- ø:).- ...." ~ : 7"'- '; ~ ~ ~-. !'1. ..u¡_ t"~ ~ ; ~ ": ~ 'i ! '¡ I[ t-.... ., q 'î-"'¡" '-~!' fM} ',-,i ! L- I '-" l . \. J_~ m:ij'j}'ï:;~bdpt i) r Form 10-403 Rev 06/15/88 ~f\lasÌ\a OJ! fi: S~:~ CO:1S. (;c:mn!s;;¡o;: Ar(;~~'Jr~:;(3 SUBMIT IN TRIPLICATE " ~. " " MAY 13 'B1 06: 17PM LINce. DIL.LON . . .\ ··..·····Î A .' .: (\,..' " .' - .','f'c, .' . ".... ,........... tt. .; . ,:-;.' . : " . . !~~" .¡ç~: ....~. \' 0' .. .... ':¡ . :. ': :....., . . ~... to'" .., . ,...". ., f I . "I:;;:~:' ,:: . :I:r,; " .:¿.' ....!' '. . . .fI. , , . . . . " pro~é~~ie for M.1T on DI!lcn pi.:1~'S~J!~ InjeëtQE . .. . . :, . . . . . . . . . P.3 . .' , " . . . :. ~ '. : ' i 1. Record dåuy tubing, casing, ~nd :outer casing pressuré& for a consecutive. ! ,. '. three day perio,d: . . .,' " . .. . . . 2. ' tncreàsecastng pi'eQuré by' 200-p~~,; . . .' ,tiriue recol'dlng daily tubing, casIng,' . anØ outer casing pressures for an .~,,~;.jO"1&II, consecutive, four~ay period... '. . . , . I' . '. " . 'Well ,: , IDi-12 . , , . ~\' ] . '. . .' " . . . . ~ssurel' Recorded By: . . . . ..,; . . . '. .' ~ . ., . .. .' . , . . " . . .. .' re ¡ .' . '. .# . . . ' . "1'" . '.t' \ . . (~ r , . ..' ? \I - " . . .. ,oJ . -, . .' ,.. '. . , ( */ ~Q~ Spud Data: Surface location: ~ locatIonI Ete¥otIoftt TO: PBOt Caelng: P.,.,aratl«tl: .;~¥i InItIcd pa'*'tfal~ :(f':¡ Infttol stIrnuIa~: .ß.~~ Cored I~; DST tntetvM and Relub: "~; '~ f"...j Log IrMntory;s "'''''~ " ....~ .... ... SOUTH MIDDLE GROUND SHOAl ADL 18748 WELl NO. 12 HEULOCt< CONOLOUERAT£ ÞLATFORU DIllON 112""1 1ÞI 4, Slot . 173' fSL. 1713.S" f'M. hI. 35, TeN. R13W, Sou. TØ - "I' FEL. 4431' FNL. Seo. 3. T7II. R1_, s.u. ,,0- kB 12000' 1VD 10"'" .. \tU' 1'W 1«3' " M-, M.S, ea.Int _ at '''' wfth 1770 .. øment . III". 40 and u.lf N-8Q an. __,5 eatnt .. at 1043.. with 1nao .. oement .,.. 23 and 21' S-., u.w Nt at 10174-11173' """ 380 II:. cement 0..\'. :;"',:J ,J¡f"7 ¡?,,~J" ,'5 0-1: 0-2: 1DÍ :.1-'1840' , ". $-' oeSO' \, ~10'81' '.:-"015'· . ·;-11011'. );, ;2-11275· l' ..04-1 '310' 1 HO:S-'145O' 0-3: 0-4: 73 ./ I -;' 1"'1$' .cemellt Squøad 181 BOPD. æ7 BWPD. 241 UCF'D None i NOne , NoM IEL-SfiI. BHC-CR. all 1fJ2oV11. .....II'2Q.17O. ~~N ~ tracer-.,rnn.r 7/11173, tnroer-............ 12ft 1113. Iraoer-t.Imperabn 1Q131J74, AA traw pìofIIe ~, 1~ 1/7', 7~ 11231I5 CDrtIPIeØen Record .-... .- -... .-... .-- lont St&t: I 1. Cameron 10'" Nom Duo! lubin, hafIIV 2. 3 '12" Suttted tub1ng pup 30 3 '12"' 8uttNnI tultlni -lAB coupIfnp ... 3 112- euttr.t. eM 2 71P SuttNlI XO 5. 2 718" ButIrtø tubfng _ .. BaIw penn.. fIOwhectd . 1/1- ad 7. 27"" 8utIrwte lubin, ,""'" ooupll. a. 2 718'" But...... pup Jt- .. 2. ttr BoIw 'f' ft'ppIe. 'W 14 ,0. 2 ttr ButtNø and 3 1/2- ButtrtÞ XO 11. Seal locator . ". 12. Seal -mbIv . 13. Bull no.. ..... out IUb o.pth 3$' )7' '0035' 10038' 100'" 10047' - , 1 OS.' " 0." n 070' ',011' 11 072' 11 093' \tQ84' Short Stmg: A. 3 112" auttru. tuWn, wi. aoupIInt. B. :)'/2" Buttrutt on4 2 ,¡a" ButtrwlI XO C. 2 7/1" ButtNN pup Jto. D. ..... 2 7/r R-NfppIe ·L1 t7 14. (M n&ß "'7/84) /~ L.. - I,¡'''£U'/€ N'1' {)ß,j.,.;f1Jc ~,(J"'; {~ ''J,O!7 '0033' 10034' 10041' 100'1" Baleer Model F-1 pier fill- bani Baker Seal ... ..be..... thIOllfh pier Þut not attIched 10 10.... Ib,. . 118" 40 Is 43.5' C5A 10'31' " Baker Ma.... r-1 pier 12 PBD 11123· 10 12COO' 1 2 3 A. 13 318" 54.:J' CSA 1 ~ar e 0825-,œe 1 01 US' 1_11' 10ecr 11081' . . Page 1 of 1 ,""1. Ayer, Phil M -Alaska From: Ayer, Phil M -Alaska Sent: Friday, January 17, 2003 12:02 PM To: 'tom_maunder@admin.state.ak.us'; 'winton_au bert@admin.state.ak.us' Cc: Dolan, Jeff J Subject: Unocal Dillon - D-14 MIT Results He aware a bundle test on Di-14 was attempted on 12/23/02 without successful results (the test lasted less then 30 seconds). ¡ of the bundle test indicates the tubing likely failed just below the standing valve during the test. f03, conversations with the AOGCC indicated mechanical integrity could be obtained for a well that failed a pressure MIT if it could ~n by another means. One method, an injectivity test followed by a static temperature survey (that indicates no fluid exiting the was discussed in particular as an acceptable method. Jr injectivity test was performed on this well on 1/14-15/03 followed by two static temp surveys. A total of 2500 bbls of 72 degree as injected at rates ranging from 2500 to 1500 bId. Analysis of the temperature surveys indicate the casing in this well is not and all fluid is exiting the intended zones. e temperature file is too large to send via emaill will hand deliver the temperature surveys (baseline and post injectivity test ) to you today. I will also hand deliver a copy of Di-14's CBL which indicates good bond. The well schematic has been attached. s requesting MIT approval on this well. Please advise. This is not a request to determine whether the well is depleted or not. We realize that this is a separate issue. Phil Phil Ayer f- [" \:,."" '': I'" ï L. r ~w ~""~. Unocal Corporation 909 W. 9th Ave, Anchorage, AK 99515 email: pmayer@unocal.com 907-263-7620 (work) .< : 907-250-2711 (cell) 907-263-7847 (fax) 111712003 'J e e Dillon Platform - d^"!.,,, n¡¡ & ÜrJ(:¡," Meter Daily Long Short 9 5/8" IlIje w~a b; Hour I Reading Rate String String Annulus Wt Field Rep Barrels PSI PSI PSI Te 4/03 4:00 380 3000 500 500 Hole full. Began injection. 72 At Surface TomM. 6:00 480 3000 950 950 72 7:00 585 2400 850 850 72 7:30 669 1800 850 850 72 7:45 695 3000 1300 1300 72 8:00 723 2600 1400 1400 72 8:15 758 2600 1350 1350 72 8:30 787 2600 1300 1300 72 8:45 818 2900 1400 1400 72 9:00 861 2600 1400 1400 72 9:15 884 2600 1400 1400 72 9:30 926 2600 1400 1400 72 9:45 954 2500 1450 1450 72 10:00 987 2600 1400 1400 72 10:15 1014 2500 1400 1400 72 10:30 1045 2500 1500 1500 72 10:45 1070 2400 1500 1500 72 11:00 1104 2400 1400 1400 72 11 :15 1130 2300 1400 1400 72 11:30 1155 2300 1400 1400 72 11:45 1181 2300 1400 1400 72 1/15/03 12:00 1208 2300 1400 1400 72 12:15 1235 2300 1450 1450 72 12:30 1260 2300 1400 1400 72 12:45 1287 2300 1400 1400 72 1:00 1313 2200 1400 1400 72 1:15 1339 2200 1400 1400 72 1:30 1364 2200 1400 1400 72 1:45 1389 2200 1400 1400 72 2:00 1414 2200 1400 1400 72 2:15 1444 2200 1400 1400 72 2:30 1467 2200 1400 1400 72 2:45 1492 2200 1450 1450 72 3:00 1517 2200 1450 1450 72 3:15 1543 2200 1450 1450 72 3:30 1567 2100 1400 1400 72 3:45 1592 2100 1400 1400 72 4:00 1617 2100 1400 1400 72 4:15 1643 2100 1400 1400 72 I I 4:30 1666 2100 1400 1400 72 I I 4:45 1690 2100 1400 1400 72 I I 5:00 1714 2100 1400 1400 72 I I : 5:15 1739 2100 1400 1400 72 5:30 1763 2100 1400 1400 72 5:45 1788 2100 1400 1400 72 B 6:00 1811 2100 1400 1400 72 7:15 1927 2100 1400 1400 72 I I 7:30 1950 2100 1400 1400 72 I I 7:45 1975 2100 1400 1400 72 8:00 2010 2100 1400 1400 72 I I 9:00 2103 2100 1400 1400 72 I I 10:00 2182 1800 1500 1500 72 I I 11:00 1500 1500 1500 72 B 12:00 2320 1350 1400 1400 72 13:00 2377 1400 1400 1400 72 14:35 2479 1400 1400 1400 72 15:00 2511 1400 1400 1400 72 I I 16:30 2600 1400 1400 1400 72 ~ 17:00 2634 1400 1400 1400 72 17:15 2650 1400 1400 1400 72 At Surface 17:17 0 0 0 0 Stop injection. Press to zero instantly. IIII/LU NI¿:::>U ~ IVI l,;:luocuments and ettmgs\o¿::>o¿pmaILocal :>ettmgsl I emporary Interne¡ r-lIesluL"':>'Ilul-l'lmj I es MOl ;:,nee¡ U':>Ull::> .XIS ui Welllnjectivity Test Date 1/14/03 -1/15/03 Well # 14 -14 Inj Test Hot Sheet 030115 .xls Test Sep. Well Test /¡ I': 200;' Jeff Dolan 1/17/2003 7:56 AM 1000 2000 3000 4000 ~ 5000 ŒI ~ ex: .s::::. - Q. ~ 6000 7000 8000 9000 - 10000 11 000 Di Baseline Temperature Su y Bottom Gauge Temperature 60 o 80 100 120 140 160 180 -RIH 12/17/2002 POH 12/17/2002 --'RIH 01/15/2003 1+ 00:30 min in POH 01/15/2003 I + 07:32 min out -RIH 01/16/2003 I + 08:33 min in POH 01/16/2003 I + 15:52 min out Shut in for approximately 1 month Injected for 24 Hours Open perforations 9,809 to 10,310' O:\OOE\OOEFiel OT Compo~ite OT 20030117 .xl~ T emperatµrechart 1000 2000 3000 4000 tb 5000 m ~ IX .c 'S. ~ 6000 7000 8000 9000 10000 11000 Di-14 Pressure Survey o o PSI 2000 4000 500 1000 1500 2500 3000 3500 RI H 12/17/2002 POH 12/17/2002 1+ 15:52 mÎn out -RIH 01/15/2003 I + 00:30 min in POH 01/15/2003 1+ 07:32 min out I -RIH 01/16/2003 1= 08:33 mÎn in I . I POH 01/16/2003 1+ 15:52 mln o~ - - ____n________________________________ In ected for 2 Hours o bbls - ----- -- ---------------- Static Shut in 1 mo th Jeff Dolan 1/17/20037;56AM posite QT 20030117 .xls Pressure chart .e~!!-.'2.~ ~~!!. Spud (1cm!; ~rfa~ l.acntl_! ~b.urfQIriI Un::aUoo; EJad(Onl T'D'I JI'II{1! ÇI)""~1 Ptlrf9f'crifan'i II'IIUal f"Qtlntlall Irl'~1¡1 ~...ll¡tloF'l:.'::'; !!!"'tvI>lr Dð~!". .--, C6r1Itd IntvvlJr,õ .-'7) þ~ Inianal.. and R.1lll1b! L6~ 1'~lIfYI ~OI.JTIi MIDDLE c::¡:{Q\.IND ~tlQA', ,A.tJL un46 I...,'tl.l NO, 14 HtMI.OtK CONOl.()~t.RA.1'E. PLATrOItU DILl.ON . ,,,*,, t~ t.1j 04, Sltlt ,), ~as PlatfMWI OOlon $01'" ~ 1710' FWL. g.c.. 3.5, T1IN. R1JW, s,M. 1D - 'IUÐ' 'FN..t t,,· twL, ~ !P), 'rm, ~; )'11, $.M, 1 00' KB-U$i. 11)500' T'I/{I! 1191!1" lCJo4.0' 1W! ""0' 20", D~. 90' H-..o Ça.lnll "' ~ '10' .Ith 'UO IX, ç:mt 1! ;van, sa) K··It~ cHlKi:Nt ~ 1:Jon' whh 1~(I ')1,11II11 III 5{8" 40. 4W £-15 éewIftQ Mt at 16'2'" 1Iftt\ 9~ 1fII. cm\ 7", i\'i1j llMr ..í It i~, oSOO' wrth 1~O II(.. CiIn'I*l'It Õ-,! 1801-08204' 102]3-'1]240' CJ-2'! i88.!i-uflll's· 10243-1024&' (1'22"'931+ ~1; 1P~1()-·lQ310· tl9"7- 652' a...,}ff~ 10102,·101C17' 1012&-10'J3' 10' 77-'OUl':!' ·,01(11..,0114' ,0200 1Q~05' 1021 5....1 O~25' 20QI ~t-þ, .:¡,I!; e;wf'D, 4Í1~ UŒD NDn. NAn. N61'1t þlp,.-!SP, FDè-CIR. FDCuCR.. 4 Am'I DI~tå" 21'2006 ['.;f( 12'121J'76, 7/21171!1. 1~4I1IO _ ~mpf.~i)n R..c6l'd. LDnIl string; I. t(l" ç~rGn byaf ~ 1""119- 2, J ,~,¡ N-ISO þyttn" twb/"!i ;), J '/".1." l'uttre.. tublnq I'YP 4. Jet P'ymp Adaptor .5. (OOI: ;)" ~ ''E'' tavt~ .vz,-iò9:, s. ~ 112" 8::Ù) mid Jo'12 Bl.lt.tr.t.~ Y.O 'J. ~ 1/2" 8.tU....... wblflg ~u~ tJ, :!¡;.al Lác.tDr V, $.a.aI "--ni~y i 1';1, Mul..ha. ' SPlCII't :5.tnl'1ii A. J in" N...8Q BU,:\I')II tub1ng (AJt run ðr'2M') JUnk: 5' ~ 2-1/8- !:iun J' 8tmt: S' I Z-1/8" Gun 8~ Wt~ een~r~11¡'f [Mpth J¡J' 1i14sa' 1144:115· ,48g· ¡+fit" '''IiII)" ø~u' 9~21' , Ø:¡47.~'" "i,ü' if}· 'r~,I('_ ",/70. ':Lll'lk Gild f1.1'1 . 10;)W ....!sTD 104$Q' 1Í1 1 O~OO· J :2 ....... . ..r-7';"r/'l" ,7". I' ,///>~.,',- ;. t 20" 83 & i!JI CSÅ 810' 1;) M" It!' CSA. H11" . 7" 26' Un.r Tap 'lit 1M3' e-- '~"1ali 4:!'.~' ç;;,i. IiII:U' Í118/)II-g.$'lo4' ~*.~" . 91.52' M 10102' :" )II iD H,IH8' ~ 10210-,Ø,),O' , ~_... ." 5"~ ~ . 0 F' 0 ~~: N , , . . ~enwnI fJJtmd ~ >- c - r.;;~þ ....... 0 c:..l t- '0 i)' ¡;;::) - en c-..J I ~,.." I V) "š I/) VDL GAMMA RAY I c I> ~, VI Z t.'!'...! 1'V'") E Z - W c::::> QI h" C') C::J <::.;) 0 a - .0 C".-J . 1:0 ,:':, . .. U,I 0 U ':~ ;; V """'......... ¡:: ~t! w AMOCO PRODUCTION CO. 10 .... FILE NO. COMPANY w i..I....î <.;:)0 I/) "::~.- = 0 ? '. 0.. -' We..:> 6 tt\ U (tic: 0:: S.M.G.S. UNIT 18746 ; 14 0 '-Ú I.J....I ~<b U WELL « cð - xa r-~ L; ,- ~ a . - .~ 6 ~ ;:: 0:: °1 FIELD SOUTH MIDDLE GROUND SHOAL l/) I{'(' « .~ .....J ) en « ;:. ç' > CG COUNTY KENAI STATE A LAS KA L'J ~ o ,':; - ~ 0 N . LOCATION: Other Services .:j, .: . l.J..J W - 2 .:.... ¡;"..; , , II ~II' 600 IF. W. L. & 1575 F.N.L. SPERRY SUN 0, C ~ > .¡ CJ V) GYRO i::> ~ c:ì « ! W loLl l'..J V) A. PERFORATE ;I~ v ~W < ¡: C i J Coil C) 35 8N OW lli 0 w 0 SEC TWP RGE ZC ~ loLl f ,Ll.! --' U Q 1 Elevations: j---i(L :> cr.: I . M.S.L. 0 100' ~ ""'.~~ t3 4 O~ Z Z'" , ' Permanent Datum Elev. KB LL' :.) I- 0< , K.B. "'.. .. - caZ i , -1Q.QFt. Above Permanent Datum -,- I.:Q <J: -- Log Measured from K.B. DF WJ W ....... (J') ~ W ZO _ 0 ! Drilling Measured from GL 0 u cr:: (J') Q.. 0 ;::)ëi) "it I . . ~~ ::;) to- I. I VI 0 ~ Z Date 2"'23-76 CSG. RECORD Surface Protection Production Liner ~JIZ ¡.- Z Q..« ::; !AI I r cY 0 U I Run No, ONE Size 9 5/¡j ::1 cY - ~ A- D: Depth-Driller 10 460 Wt./Ft. 43.5 2t";' V) 1-- W I- ~ !AI i I I V) l.L1 I- U 0 A. Depth-Logger 10~4b3 Grade S"95 P..1fo <::¡, a::: I- ~ < - 00 i I _J U 0- i - I Bottom Logged Int. 10 4c;"7 Type Joint BUrr BUTT uo z ;;;:;: I Top Logged Int. g. ~OO Top ..... SURFACE 9.3~1 z en - J: VII ;;¡¡;:: Ë :I: W; Measured 1 1 r:;7 Bottom -<1. 620 1 0 .1J.bO M~ <I: ...J ~ ~AL' ilA T R cr:: c;( Q. 9300 ype Fluid in Csg. PRIMARY CEMENTING DATA ..:¡ _J ¡.- ::J C W Density of Fluid ~. I Type Cement SE I-< <..: T Q ~ a ,'-, 'r . Fluid Level FULL Vol. of Cement 0.,.. f- a I i ! UN 4- 1- a Max. Temp. Deg. F. "ai_- Additive . t'J Ii) ~ ~ I ¡ i Tool Series No. 1408M % Additive Q Lf 0 >- i I I : I :_1 = ¡ r-'" W ~ l- +- ! ! i Tool Diam. 3 5/8J! Retarder ¡- V) r- - .:r: <J: oo¡: ~ >- I/) I ¡ I Standoff Size CENT. % Retarder . I- :r: .....J Z I Logging Speed 30 FPM Slurry WI. - W ¿: « WI/) r.n j II ~ C) .....J cY 0:: I-w l- I , ¡. R/ A Log Type G/R Water Loss LU 0 cr:: V Zr.n - ; I ." "'It. -- I- 0 0 0 ~ « -« Z I T.C. 2 Drlg. Mud Type z w l- .. U :::> I w - Sens. Setting ~UU Drlg. Mud WI. w u - ~ Zoc : I I \ ~ - <:( ...J try C aU I API Units/DiY, 7 PRIMARY C'ENTING PROCEDURE w -.-.J (Q 0 ~ - 11 l- I I -Z a.. Truck or Unit No. ¡jOt3 Started Pumping UO 1 Þ.2 '. E Preceding Fluid ,I ZU u t:L U ..J L I 1-- « i « « Location KENAI Plug on Bottom 090 PZI Vol. IU Bbls. w (j - Ii (/) I C 7 HRS. U~1 l.JLI Returns: ;(;~¡X X lp¡r>f.¡iI a: ~ . Opr. Rig Time Pres. Released None UJ ! J: II: « ! i Recorded by t-1 f LLS Started Bond Log U~j JL.) Pipe Rot. During Pumpi~ No C) 4( a::: ! : _J :E Witnessed by UTTECHT Finished Bond Log '123 P23 Pipe Rot. After Plugdown~ No 0 w . ! -¡ "- II: ~ I . .. ·SItZ REV -- - ---r-- - - - - - .- - - - -i -1 -- --r---+- t-1_ ¡------ - ----r-- --¡-- - ---- - ---- -- -- - --- - -- ---- ----- - -.-. --- ..... --- - -..-' --_.~_. - -- ----- --- - .-..~ .-- - --._- r--__ - - - ±- - - - - - - - - ---" -I , o t--i t-1 ¡-- r----- n h~ " j ~ - - - ---:J n .. - - r- , 1 ~ - - -, ~ ; --. -, ":;iIo I ~+ -[ . ;;¡;- /Ë I = - - - 0 i --, q - I ,.) ""] r .1 r-- (,þ .þ o o \ r- I: - r -., ~ -~ c.o Ut o o r--1 r--- r- ~ .-- r----- ,- h ~ I r- r-; - - - -'/" ---. ~ ~ ---; -~ -f--, ~ , - - - - -. - [ ,r I--- - +- --"- ---.- -- ---- - 1- __ ___ ;: -.--- ---- ! ~ r----- - ~ . t=- ! -- or - - - - - = - - ! -+ __u ~ - I - ~ I I e - I r- I I I 17- r I I I I I ;- I~ ..¡, .. -~ I , rJ ._- " ~ ;~ .. .. r , ~ ¡ I J r II"'.. I I., · r r. 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I þ' I I 1'1 .- I I - j , ,. f - I I oj ~ .... - - ~ -- 4 - ....1-- ---j I I ~ , - ~ ..... - -~..t~ ..... i..ooI"'" ~ - .... - .- ~~ -- .:"" - ( .. -- C .. Log FR. I'a - --- -.-:-- "-"''''-'''~I'-''''--''-- -.. ~-i-- .-..---- -----..- -:"- ) . ~.- ~- __n , JI Log TD. .... , ..... ~ ;;;. n g :::- -. '?S; þ:~' ~ - r-:) 1;::.;." n ' ~. ... '~-r :;.,..: . . ---.,. ..--- ....-.- ......... .~-- ·····--··..-t---··-·-··r ,..-... .. G) =i=-=- - .- =~-=t~- -- ~--t~-:t~+·~· .....0.+-.-. - _n_~ ---~ . .... ··1·· ..- -f...n. 70 ...... 7 API UNITS 16 40 100 200 MICROSECONDS 1200 "O¡ .. ¡: I I I ,ILl ¡!J ;t PERCENT UNBONDED PIPE ~.~ SIGNAL '''''-.''...:. ('t) Øf:, J;/ RADIATION INTENSITY INCREASES AMPLlTU DE INCREASES ,.. . GAMM A R AY DEPTH COMPRESSION WAVE VARIABLE DENSITY AMPlITU DE - Company AtA.OCO PRODUCTION CO. Drillers T.D. 10ß460 Well (, ~ ~ IJNJ T 1 874() "4 Loa F.R. 10&4S7 . , . ..,., t" I .., ~¡ I .' V I I " K........~ ~ ~ . i .~ ' ... r- t=f= e T I ... 1 B 3~' .~, '- I I I -¡ I - , ¡---"I I ,.,'¡f' I , i - I I 1IIIi.. - - !!a. - - .,., I ~ ~ tI!' - lOt ~,-j-) tI!' ...- - c ,.' '""'" - ~ ,- -~ ~ ~ - ( ... ,.' .. log FR. ~ }~) -_.~- _..-. ~- .-_. .-'..---- ,,---,- ------ )--- ,-.- ,--- .--.- --..-... - ----- ~o.-, -.-- I ¡ .- - log T.D. ..... ,. - "' 'iio. n g -. "". ~ -.;..c- n ··.·n ~' ~+ 'YlIf', f~ - - -- ._---,-- _._--- ---- -.--.- --- ..'_.'--- ''',,' ."'___' __.___m...~...._.... __n__.. _ .- .-+:-.= ~- -- r-t--t'-=t:~:'1=· ~-:"'r - -1.-. - '-"c- -" ~_.~. -'- '_h .--- ---._--- 7 API UNITS 70 16 40 100 200 MICROSECONDS 1200 I I I PERCENT UNBONDED PIPE SIGNAL RADIA TlON INTENSITY INCREASES AMPLlTU DE INCREASES ~ . GAMMA RAY DEPTH COMPRESSION WAVE VARIABLE DENSITY AMPLlTU DE -- Company AiJ\O co PRODUCTION CO. Drillers T.D. 10,460 Well s. ,"'"' ot5,.. UNIT 18746 ¡'¡~4 Log F.R. 10~457 Field SOUTH I'll DOL E GROUND SHOAL Log T.D. 10~463 County KENAI Elevations: State t.,J " ~ k' /I. K.B. 100f D..E~ IIÍII'tII!W ~I 0 \..7. _. .. o :0 1: .. .. .. .. .. > ~ _t..." \r- I CEMENT STRENGTH PERCENT OF SIGNAL IN UN80NDED PIPE Spacing 5' AVERAGE COMPRESSIVE STRENGTH (psi) 100 4000 50 CASING THICKNESS ( inches) 30 20 10 ? ~0'6 0.5 0,4 1000 5 e e Page 1 of5 Ayer, Phil M -Alaska From: Ayer, Phil M -Alaska Sent: Tuesday, January 14, 20032:38 PM To: 'tom_maunder@admin.state.ak. us'; 'winton_aubert@admin.state.ak.us' Cc: Dolan, JeffJ Subject: RE: FW: D-15 Bundle Test Results Tom and Winton, We request approval on this MIT for the 500 psig test. This is not a request to determine whether the well is depleted or not. We realize that this is a separate issue. Phil Phil Ayer Unocal Corporation 909 W. 9th Ave, Anchorage, AK 99515 email:pmayer@unocal.com 907 -263-7620 (work) 907-250-2711 (cell) 907-263-7847 (fax) -----Original Message----- From: Lewis, Richard W Sent: Tuesday, January 14, 2003 2:12 PM To: Ayer, Phil M -Alaska Subject: D-15 See excel MIT form attached. -----Original Message----- From: Ayer, Phil M -Alaska Sent: Tuesday, January 14, 2003 11:21 AM To: 'winton_aubert@admin.state.ak.us' Cc: 'tom_maunder@admin.state.ak.us'; Dolan, Jeff J Subject: RE: FW: D-15 Bundle Test Results Tom and Winton, I will hand deliver copy of Di-15 CBL after lunch today. Might be good to put a face with the names. Phil PhilAyer Unocal Corporation 909 W. 9th Ave, Anchorage, AK 99515 f' r··> , 1/17/2003 - e Page 2 of5 . email: pmayer@unocal.com 907-263-7620 (work) 907-250-2711 (cell) 907-263-7847 (fax) -----Original Message----- From: Ayer, Phil M -Alaska Sent: Tuesday, January 14, 2003 10:13 AM To: 'winton_aubert@admin.state.ak.us' Cc: 'tom_maunder@admin.state.ak.us'; Dolan, Jeff J Subject: RE: FW: D-15 Bundle Test Results Resubmitted - I used incorrect email address for Winton. Phil Ayer Unocal Corporation 909 W. 9th Ave, Anchorage, AK 99515 email: pmayer@unocal.com 907-263-7620 (work) 907-250-2711 (cell) 907-263-7847 (fax) -----Original Message----- From: Ayer, Phil M -Alaska Sent: Tuesday, January 14, 2003 10:10 AM To: 'tWinton_aubert@admin.state.ak.us' Cc: 'tom_maunder@admin.state.ak.us'; Dolan, Jeff J Subject: RE: FW: D-15 Bundle Test Results Winton and Tom, The CBL on Di-15 is being copied and being sent over to you ASAP. Bond looks good. Phil Phil Ayer Unocal Corporation 909 W. 9th Ave, Anchorage, AK 99515 email: pmayer@unocal.com 907-263-7620 (work) 907-250-2711 (cell) 907-263-7847 (fax) -----Original Message----- From: Ayer, Phil M -Alaska Sent: Tuesday, January 14, 2003 9:54 AM 1117/2003 e e Page 3 of5 ~ To: 'tWinton_aubert@admin.state.ak.us' Cc: 'tom_maunder@admin.state.ak.us' Subject: FW: FW: D-15 Bundle Test Results Winton, Hopefully Tom can respond today but if not please read and advise. Thank you Phil Phil Ayer Unocal Corporation 909 W. 9th Ave, Anchorage, AK 99515 email: pmayer@unocal.com 907 -263-7620 (work) 907-250-2711 (cell) 907-263-7847 (fax) -----Original Message----- From: Ayer, Phil M -Alaska Sent: Tuesday, January 14, 2003 9:49 AM To: 'Tom Maunder' Cc: Dolan, Jeff J Subject: RE: FW: D-15 Bundle Test Results Tom, We did perform the 500 psig and the 1000 psig bundle tests for 30 minutes each and I will send you this information in the chart form. We do believe there is a possibility that we could dispose of fluid at 1000 psig, 500 psig, or even lower as the amount of fluid we need to dispose of everyday is small (80 to 300 barrels) and we would be injecting no more than 12 hours a day. In addition the reservoir pressure is depleted as it is roughly 2500 psig. With a full column of fluid the well would be in a roughly 2000 psig overbalance condition to the formation and so with 500 psig at surface we would be 2500 psig overbalanced. This may be all the differential pressure we need. In fact we may be able to do it with no pressure at surface - we could simply fill the well with 250 or so bbls a day (static fluid level at 2500 ft to 4000 ft depending on the well) and come back one day later and the well will be back to the same fluid level. Just prior to being shut in the well was producing 660 BGross/day with a 90 % drawdown which equates to slightly over a 2000 psig of differential pressure, so 2000 to 2500 psig of differential pressure in to the formation for 4 four to 12 hours a day should be adequate to dispose of the small amounts of fluid we are disposing of. My understanding is that the determination of "mechanical integrity"" on these wells is a separate issue from the "depletion" determination as per our "parallel path" discussions we have had. I realize that the ultimate decision on disposal approval will come from having both "mechanical integrity" and "depletion" in any producer. My inquiry below however is focusing on mechanical integrity. I will attempt to send a CBL to you if one exists on Di-15. The well did exhibit 10 % water cuts initially gradually increasing to 80 % cut over 6 years. Phil Phil Ayer -, t"" r) ( 1/17/2003 e Page 4 of5 e , Unocal Corporation 909 W. 9th Ave, Anchorage, AK 99515 email: pmayer@unocal.com 907 -263-7620 (work) 907-250-2711 (cell) 907-263-7847 (fax) -----Original Message----- From: Tom Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, January 14, 2003 7:35 AM To: Ayer, Phil M -Alaska Cc: Hartz, John D -Vendor; Crandall, Robert P -Vendor Subject:.Re: FW: D-15 Bundle Test Results Phil, When Jack and I looked at your pressure information, it was not clear that the "intermediate" pressures were held for 30 minutes. There are comments that indicate to hold the pressure for 30 minutes, but the actual reporting section is not filled out for either the 500 or 1000 psi increments. It is possible that you can make the case for the low pressures as indicating integrity, Do you believe that the actual disposal pressure would be 500 psi or below?? The other item of consideration for this well is that it is a producer and the determination of "depleted" must be made. I have not reviewed this file for mechanical integrity information. Does a bond log exist for the well?? I will be out at a seminar with most of the staff today, As I am able, I will get back to you. Torn Maunder "Ayer, Phil M -Alaska" wrote: om, hanks for your prompt response. he well tests at lower bundle test pressures did show "trending to stabilization". The bundle test to 500 psig showed no ecrease in pressure at 15 min and a 499 psig at 30 min recording times. Would this suffice as a MIT as long as injection ressures do not exceed 500 psig? 'hil Phil Ayer Inocal Corporation 09 W. 9th Ave, Anchorage, AK 99515 mail: pmayer@unocal.com 07-263-7620 (work) 07-250-2711 (cell) 07 -263-784 7 (fax) ·---Original Message----- , , rom: Tom Maunder [mailto:tom maunder@admin.state.ak.us] ent: Monday, January 13,2003 11:52 AM .. '0: Ayer, Phil M -Alaska :c: John D Hartz; Bob Crandall ,ubject: Re: FW: D-15 Bundle Test Results 'hil, !:1.ck Hartz and I have reviewed the "bundle test" information you have provided for Di-15 (176-045). Jack and I 1/17/2003 e e Page 5 of5 - oncur that it is not appropriate to approve this test. ~ccording to your record, the pressure was increased to 1510 psi and the observation period began. In the 30 linutes observation period a total of 120 psi was lost. This is less than 10% of the total applied pressure which oes fit the requirements. However, it is not evident that the applied pressure is "trending to stabilization", ~ccording to the provided information, 65 psi was lost in the first observation period and 55 psi in the 2nd. There oes not appear to be any clear trend except continued decline. It may have been appropriate to extend the bservation period to an hour to confirm stabilization. : is uncertain if the pressure loss experienced was due to your standing valve leaking or whether the casing was ~aking. Regardless, as noted previously, it is not appropriate to approve this test. 'lease contact us with any questions. 'om Maunder, PE ~OGCC Ayer, Phil M -Alaska" wrote: m, ~ request approval on this MIT. Please advise. il HAyer ocal Corporation 9 W. 9th Ave, Anchorage, AK 99515 lail:pmayer@unocal.com 7-263-7620 (work) 7 -250-2711 (cell) 7-263-7847 (fax) --Original Message----- [)m: Lewis, Richard W nt: Sunday, January 12, 2003 5:32 PM : Ayer, Phil M -Alaska : Richard Lewis (RichardLewis) bject: D-15 Bundle Test !re is your Bundle Test Report «Di1-5 Bundle MIT form 200301 09.xls» ;k Lewis F- co;: 1/17/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Bundle Mechanical Integrity Test (Standing Valve or Plug in Tbg Tail) E-Mail to;Tom_Maunder@admin.state.ak.usandBob_Fleckenstein@admin.state.ak.us OPERA TOR: Unocal Alaska FIELD I UNIT I PAD: South Middle Ground Shoal Field / Dillon Platform DATE: January 11,2003 ............... PTD: 1760450 s p s 9,324 95/8" 40# N-80 3.5" 105 450 445 443 10:02 PM Well #: Di-15 12,019 500 90 450 445 443 COMMENTS:·· Test for 30 min before going to next pressure 9 5/8" 40# N-80 PTD: 1760450 Well #: Di-15 COMMENTS: PTD: Well#: COMMENTS: f"(í TBG. INJ. FLUID CO~S F = FRESH WATER INo! G = GAS INJ. ~~.~ S = SALT WATER INJ.;;:~ N = NOT INJECTING IT' TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: P.P.G. DIESEL GLYCOL SALTWATER 8.413 DRILLING MUD OTHER Grad. 0.00 0.00 0.44 0.00 0.00 WELL TEST: Initial 4 - Year Workover Other Distribution: orig - Well File c - Operator c - Database c - Trip Rpt File c - Inspector OPERATOR REP SIGNATURE: Joel Neighbors ,AOGCC REP SIGNATURE: Di1-5 Bundle MIT form 200301091-R1.xls 1/17/2003 RKB to TBG Head = 32.90' Tree connection: 3-1/2" 8RD L. ~ ~ 6 Top 162 jts. STD Couplings! 4.250 a.D. 16 G1 G2 G3 PBTD = 13,000' TD = 13,133' HOLE ANGLE at 4,000' = 50.300 D-153-14-98.doc e e Dillon Well No. 15 Actual Completion 3/14/98 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20 85,95 H-40 Surf 656' 13-3/8" 54.5,61,68 K-55 12.415 Surf 3,500' 9-5/8" 40, 43.5 S-95, N-80 Butt 8.755 Surf 10,590' 7" 26 S-95, P-ll0 Butt. 6.276 10,263' 13,133' Tubinl!:: LS I 3-1/2" I 9.2 N-801L-80 Used Butt. Rel!.IS.C. I 2.992 I 32.90' 11 ,968' SS 3-1/2" I 9.2 I L-80 Butt. I 2.992 I 32.90' 65' JEWELRY DETAIL NO. Depth ill OD Item 32.90' OCT, Type U-60, Dual Hanl!:er 1 11,968' 2.992" 3.865" Crossover, 3-112" EUE 8rd Pin x Buttress Box 2 11,970' 2.687" 5.75" Kobe Cavity, 3" Tvoe 'D' OPF 3 11,996' 2.992" 4.50" Crossover, 3-112" Butt Pin x 3-112" EUE 8rd Box 4 11,998' 2.992" 4.520" 1 ea. Blast Joint, 3-112" Buttress Box x Pin 5 12,017' 2.970" 4.550" HES, Seal Assemblv. 10' Lonl!: Unner Packer Assemblv (Set on Drill Pine) 6 12,019' 4.00" 5.890" HES 7", BWD Permanent Packer 7 12,023' 4.00" 5.020" Seal Bore Extension 8 12,031 ' 4.00" 5.70" Tubing Adapter 9 12,034' 3.958" 5.20" 1 it. 4-112", 12.6#, L-80, Buttress Modified Tubing 10 12,065' 4.00" 5.750" Scoon Guide, 5-3/4" O.D. Lower Assemblv (Adjusted to DPM Tal!:) 11 12,050' 2.992 Cut Joint, 3-112", 9.2#, L-80 Tubing. XO, and Pun 12 12,070' 2.687" Kobe Cavity, 3" Type 'E' 13 12,085' ? Crossover 8rd x Buttress (no other description) 14 12,091 ' Blast Joint, 4-1/2" O.D. 15 12,111' ? Baker Locator, Seal Assemblv. 20' Lonl! 16 12,131' ? Mule Shoe I *12.100' 4.00 Baker Model "F" Permanent Packer * WLM Set in 1977 Ta ed wI 2-114" Bailer 12,580' WLM 12,580' WLM Cleaned out from 12 150' to 12,625' 4/2/01 4/2/01 3/19/98 Fish 1-112" Bailer PERFORATION DATA (DIL) Accum Last Zone Top Btm Amt SPF Perl Date Present Condition G-1 12,250' 12,270' 20 8 4/7/98 2-1/8" UJ, 4spf, 0 deg. G-2 12,370' 12,388' 18 4 7/5/76 Unable to reperf G-2 12,417' 12,427' 10 4 7/5/76 Unable to reperf G-3 12,558' 12,563' 5 4 7/5/76 Unable to reperf G-3 12,571' 12,576' 5 4 7/5/76 Unable to reperf G-3 12,611' 12,616' 5 4 7/6/76 Unable to reperf G-3 12,622' 12,627' 5 . 4 717/76 Unable to reperf G-3 12,640' 12,650' 10 4 7/8/76 Unable to reperf G-3 12,674' 12,681' 7 4 7/8/76 Unable to reperf G-3 12,688' 12,698' 10 4 7/8/76 Unable to reperf G-3 12,708' 12,712' 4 4 7/8/76 Unable to reperf G-3 12,722' 12,727' 5 4 7/8/76 Unable to reperf UPDATED: 6/28/01 SLT 10000 DillON Platform Cumulative Gas Prod: 797 MMcf Cumulative Oil Prod :1985 Mbbl 100 80 60 Gas Production Oil Production Water Injection 40 20 o 89 90 91 96 97 98 99 2000 01 02 1000 , , - .- , , .- -- ", , 1\ 1. , ~ ¡ I í It : : , .-- - Ii '-4 - -- -- -- ,--- -- --- --- --- I --- , Oil Rate (CD) ( bbl/d ) ",,", #'!iA, R,,!; - liquid Rate (CD) ( bblld ) , --- Water Rate (CD) (bblld) Rate, (C~) : 7 Mcf/d C),URate (~[» . . --- --- Gas I Oil Ratio ( cf/bbl ) --- --- --- Water Inj Rate (CD) ( bbl/d ) "16 ¡ ¡ I81J Rate --- ' * , , ¡ , I I , I 100 10 1976 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 2000 01 02 PMA B General Platform Wtrfld Prod Plot01/23/03 15:28:39 1.0 0.8 0.6 0.4 0.2 0.0 ì g -]L.l L E \ :š KB 1 0.0 F T {;- {;- #9 MIKE TAURIAINEN, p......... Consulting Engineers .. 35186 Kenai Spur Highway SOLDOTNA, ALASKA 99669 (907) 262-4624 FAX (907) 262-5777 OJ~1r1rUW 1rœ£~~[Kj{JD1ru£[L À\ 0 'b OATE: 8, 1995 I JOB NO. - June \ CVIV"" I ATTENTION ICOMM RE: UNOCAL Dillon Platform W l!ie~@r Disposal System Plan Rev 8 ENG I '-I ,..... ENG ASST I ENG ASST I \:In v'-"''- I . GEOL ASSTI GEOL ASST\ ,;:, 1/"\1 ...v, ~ the following iter ~T A T TECH I FILE TO ADEC Attn: David Johnson Red Diamond Center Soldotna, AK 99669 > WE ARE SENDING YOU Œ. Attached 0 Under separate cover via o Shop drawings o Copy of letter o Prints o Change order o Plans o o Samples o Specifications L. COPIES DATE NO. DESCR!PTION 1 8 June '95 Reply to ADEC May 1, 1995 Letter & Attachments THESE ARE TRANSMITTED as checked below: 0 For approval 0 Approved as submitted IX! For your use 0 Approved as noted > 0 As requested 0 Returned for corrections 0 For review and comment 0 0 FOR BIDS DUE 19 o Resubmit_copies for approval o Submit_copies for distribution o Return_corrected prints o PRINTS RETURNED AFTER LOAN TO US -REMARKS Copies to: Christopher Costelloe, Unocal Alice Bullington, Unocal Marty Hrachovy, Unocal ADGC '"'David"Johnston, AOGCC~,· DNR R-fff-l-\l-É-D-- ,¡{IN 12 1-995' Alaska i)iI& Gas r,ons. Co~n . ~cIiOlaQG COPY TO j It enclosuntS e" not es noted. kindly notify us sf once. SIGNED: raœuculOo3 I_I tc.. -. _ awl. ( ~ , ee (M CONSULTING ENGINEERS. INC. Mike .E. June 8, 1995 95021 Subject: UNOCAL Dillon Platform Wastewater Disposal System Plan Review (PR95-052VV\f\1) Reply to ADEC May 1, 1995 Letter ;f>~ ~ G<> 91%, '/<'Ív .~. þp. €l.o-. . I ;j'>.^ . ~cf <? '~U , '" 6'q~ /;9.9 ~~' COn, a- , ~ .,,~ ~~q:", '",,- ~~ David Johnson, P.E. ADEC Red Diamond Center Soldotna, AK 99669 David: Attached is our response to comments and questions in your May 1, 1995 letter (received May 10). ITEM 1 From our March 10, 1995 meeting and previous discussions with Robert Dolan we believed that a permit would not be required even though the Department has the authority to rë'quire a permiffor annular injection of domestic wastewater. We are initiating the permit process by submitting a CPQ (copy attached) to you and to ADGC, Water Quality data (salinity) is included in attached Dillon 13 Salinity Log. ITEM 2 This letter and the attached injection well schematic is sealed by a professional engineer, Our March 10, 1995 I~tter and attachments are included under this submittal. Considerable information has been supplied by UNOCAL that we cannot verify, however, we have reviewed it and believe it to be accurate. ITEM 3 Information regarding the history and mechanical integrity of the wells has been supplied by UNOCAL and is attached and labeled ITEM #3 ( 10 pages). The wells were reportedly drilled in 1968, and no information is available for casing inspections at the time of installation. Available information indicates that both well D-11 & D-12 are in good condition. The 13%" casing is rated to withstand an intemal pressure of 2730 psi and the 9%" casing is rated to withstand an external pressure of 3090 psi. Surface injection pressure is expected to be less than 100 psi which results in an injection pressure at 2000' of less than 1000 psi, giving a factor of safety of approximately three. ITEM 4 Normally the facility will have about 10 people with normal highs of about 25. If a major construction project was underway on the platform an extreme high of 50 people is possible. 35186 SPUR K'NY SOLDOTNA, AI< 99669 (907) 262-4624 FAX 262-5777 'e UNOCAL Dillon Injection June 8, 1995 . 2 -- Mike Tauriainen, P.E. Consulting Engineers. Inc. Soldotna. AK 99669 ITEM 5 Attached is a calculation that identifies the expected pumping conditions. The calculations were provided by UNOCAL on May 31, 1995. The calculations show an expected surface injection pressure of about 100 psi. Injection pressures at 2000' should be less than 1000 psi. ITEM 6 Specific well log information for the areas within 500' of the discharge level of D-11 & D-12 is minimal due its relative shallowness, however, combining information from adjacent wells from the Dillon Platform should gives a good indication of the subsurface strata. The well log for Dillon 13 shows material types, salinity and porosity above and below the zones of interest. The well logs for Dillon 16 & 17 show materials and descriptions for the zones of interest. Also attached are the logs available for D-11 & D-12. Please note that the logging for D-11 & D-12 was done intermittently at shallow elevations. As we stated in our March 10, 1995 letter, the soils are typically permeable sandstones encapsulated by impermeable strata. ITEM 7 Wells D-11 & D-12 are not producing wells and their use will be restricted to disposal of domestic wastewater. ITEM 8 A Coastal Project Questionnaire is attached, ITEM 9 We will submit a copy of the submittal information to the AOGCC. Please call if you have any additional questions. Sincerely, ~~ Lv-t-Henry Knackstedt U Project Engineer hklwsdesignlunocalpe Attachments: Cover Letter to ADGC Dillon Injection Plan Detail c: March 10, 1995 Submittal May 1, 1995 ADEC Letter Coastal Project Questionnaire Mechanical Integrity of Casings (10 pages for ITEM 3) Expected Pumping Conditions (2 pages for ITEM 5) Well Logs (23 pages for ITEM 6) ~""-... i#~~~..~.-1~"\ I~t',. .,,~...+, fJ{-~ !49!!! X ,,:..?~ \ _: .. ..~. ...\....i " . ~ ~ . . . ......... if. þtID tAlJB1AlNEH ~ ~ ~... ~ 11I- $3SD-e"""}1/ ~~, ~}'.. a. ^~" ~('~..........~~~~ "_JROFE~~\~~'" '"i".....- Christopher Costelloe, UNOCÀL Alice Bullington, UNOCAL Marty Hrachovy, UNOCAL ADGC . AOGCC DNR REGEIVED ,ìUN 12. 1995 Alaska Oil & Gas Cons. C~ . ~ctioJj1gG' -_ Mike M CONSULTING ENGINEERS, INC. .E. June 8, 1995 95021 Alaska Division of Governmental Coordination 3601 "c" Street, Suite 370 Anchorage, AK 99503-5309 Subject: UNOCAL Dillon Platform Request for Approval to Inject Domestic Wastewater The attached submittal requests approval to inject domestic wastewater through non producing wells at the UNOCAL Dillon Platform in Cook Inlet. We submitted a plan to ADEC with our March 10, 1995 letter that describes the proposed project in detail. ADEC wrote a letter on May 1, 1995 requiring injection well permitting and requested additional information. We responded to ADEC with our June 7, 1995 letter which includes a Coastal Project Questionnaire and attachments. We are forwarding the attached packet of information to ADEC, DNR and AOGCC, ADEC has notified the EPA for comments. Please call if you have questions. Sincerely, , ~~ ~Henry Knackstedt /) Project Engineer c: UNOCAL ADEC DNR AOGCC REGEIVED Attachments .,lJN 12 1-995 __....t~\\ Alaska Oil & Gas Cons. C.!./JlUW! Anchoragll 35186 SPUR HWY SOLDOTNA, AI< 99669 [907] 262-4624 FAX 262-5777 .. .'1'.. .:. 4'. . ~ 4 . .~ . . . · . . ~., .- . '! .. :." '. ~ ·.4. , ..' .. , ""t#: .. ~ " .:._ ~: ":.i;·:· ..' ~ ~. . ~.. . 95021D 1 '=1 . PRESSURE GAUGE ~"...."" ~.~( CF ~.. ...~ 0 ......-. ;0 *~ tt !* 49th \*\ = ~ ~ I I . \~ Mike Tauriainen II '~~ No..3380-E ~# t.. 0/.1 -. ~\~ , ·,,~FESS\O"':.." ".n...·· ~ðß(@~~o CONSULTING ENGINEERS INC. 35186 SPUR HWY. (907) 262-4624 SOLDOTNA. AlASKA 99669 FAX 282-5777 . .. ~:. .' .. . ~.. . .~ '. . e WE'LL HEAD ee .~ .. ¡ I· . '.'" ¡ ,. ;: .. þ . ... .. .. ~. ~ '. ., .. . ~.. 0 . · ~ o. ~ . · .. I : ~ t '.: BOTTOM OF COOK lNLIT 2(j' OD . . . .. .. .. .': .. . . ... '.' ~. . . I .' ~ .' . ...... . . . .. ° ,:. .. o . ..... ... "'" ...... 0" .. " RECEIVED ¡ . ~::. ~ ;;t~:, ~.~ ." .. . : ',¡.. . : o'..:~. .0.... , ¡ . \~~ROUT (7YP) ,.'j 12 1-995 ;,Iaska OiJ & Gas Cons. C. Anchorage 1J J/Ef" OD ¡ / D-12 WE'LL 1587' D-11 WElL 2001' 9 5/Ef" OD TOP GROUT 0 D-12 WE'LL 6925' D-11 WE'LL 5867' , NOTE: THIS DRAWING WAS PREPARED BASED ON INFORMATlON SUPPUED BY UNOCAL OIL CO. DILLON PLATFORM SAS' NrS ~ i, c..; DATE: DRAWN: CHECKED: SCAl.E: PROJECT NO.: MARCH 1995 TS HK ÞS SHOWN 95021 SHEET 1 OF 1 DILLON PLATFORM SAS #8 ~ C;-::'--.-": :...::. ~i""':¡"\'ì"',' U'¡i ,: ,\', ¡: ;:: ~ .. I I; : U::.\!! j~ ..... ~ - . ":" ( .. ~':.J ! :~ i . , . TONY KNOWLES, GOVERt-- :~ -\J .__..ø.- ~ ~.~. - ~ ~ ..... DEPT.. OF ENVIRONMENTAL CONSERVATION KENAI DISTRICT OFFICE 35390 K-Beach Roac suite 1J Red Diamond Center Soldotna, Alaska 9966S Phone: (907) 262-5210 Fax: (907) 262-2294 May 1, 1995 Mr. Christopher Costelloe UNOCAL Energy Resources Division 909 West 9th Avenue P.O. Box 196247 Anchorage, Alaska 99519-6247 , .~~ RE: UNOCAL Dillon Platform Wastewater Disposal System Plan Review (PR95-052WW) Dear Mr. Costelloe: A review of preliminary information (received by the Department on . 14 and March 30, 1995), for ..the 'above-referenced facility, has been completed. .Department concerns are similar to those identified in a meeting held at the Kenai District Office on March 10, 1995, attended by Alice Bullington, Henry Knackstedt and myself. These comments together with comments generated as a resul t of the information submitted, are summarized below: 1. 18 AAC 72.010 provides Departmental authority to require· I a permit for the proposed annular injection of domestic W wastewater. The Department's position is that this ~ activity should not be allowed unless a permit is issued. ~ The general permit submitted with your plan does not apply to your proposed activity. General Permit 9420 was primarily promulgated to cover one-time disposal activities primarily associated with oil/gas drilling operations and not on-going injection activities. ~ <"ù Q The Middle Ground Shoal Field has been granted a Freshwater Aquifer Exemption by the Alaska oil and Gas Conservation commission (AOGCC). Please submit water quality data, if available, for the total dissolved solids concentration of the groundwater at or near the level into which this discharge is proposed. \Ø~ 2. 18 AAC 72.280 governs construction of domestic wastewater disposal systems where the primary function of the system (. " - ~ .. \,. _ ',-'~ c..: ';.!\' ,- -, :-'_.... .., ie (.. . ~ , . MR. CHRISTOPHER COSTELLOE 3 on all correspondence régarding the plan review for this facility. If you have any questions or need assistance, please call. David son P. E. Environmental Engineer Attachments CC: Mike Tauriainen Robert Dolan Jonathan Williams AOGCC ( {~ c',! t #7 · /-- ~ - __ M CONSULTING ENGINEERS, INC. Mike .E. March 10, 1995 95021 David Johnson, P.E. ADEC Red Diamond Center Soldotna, AK 99669 Subject: Unocal Dillon Platform Soil Absorption System Conceptual Plan and Request for Preapplication Conference David: Per our conversation, the following is a conceptual plan for subsurface disposal of treated domestic wastewater from the Unocal platform Dillon through two inactive wells. The wells are known as Dillon 11 (D-11) and Dillon 1 2 (D-1 2). The Dillon Platform is located in northern Cook Inlet at N 600 43" by W 151 0 30', approximately 3.6 miles from the Kenai Peninsula East Forelands which is the nearest coastline. Domestic wastewater on the Dillon Platform is currently processed through secondary treatment, and is permitted by ADEC and EPA for discharge into Cook Inlet. The proposed pressurized absorption system will eliminate the surface water discharge. The effluent will be additionally treated with .a deoxidizer which will essentially sterilize the water of residual organisms. Attached is a schematic diagram that shows the flow pattern of the effluent from the existing treated-effluent tank through the charge pumps, past the chemical injection pump, and through th~ 5000 psi pumps to the wells. The approximately 2500 gpd of effluent will be pumped through the 13%" by 9%" annulus to the 2001' depth of well D-11, and to the 1587' depth of well D-1 2. See the attached well casing detail. The well casings are double grouted above and below the discharge points. According to the geologic summary, the wells pass through Lower Miocene to Oligocene middle Tyonek sandstones which are in no cement contact (ungrouted) in wells D-11 and D-1 2 (which should allow effluent to move horizontally into these sandstone zones). The sandstones are stratified between thick, non-marine fluvial and alluvial packages of coals and impermeable mudstones, tuffs, shales, and siltstones. The sandstone can be grouped into three sand rich packages encased by the impermeable lithologies. The sandstone packages are 11-13SS, 14-17SS and 22-30SS. See the attached well logs for corresponding depths. j'i :..) 35186 SPUR HWY SOl.DOTNA. At< 99669 (907) 262-4624 FAX 262-5777 /": .e -- UnocaJ Dillon SAS Prapplication Conference March 1995 . 2 Mike Tauriainen, P.E. Consulting Engineers, Inc. Soldotna, AK 99669 Log derived porosities range from 15% to 30% and average 23%. No direct tests or analyses have been conducted on the sands at Dillon. Mud-log and wireline logs indicate that these sanstones wet, A simular layer of sandstone (31 st layor) at the Baker Platform has a calculated permeability of 0.063cm/sec. All other similar sands at Baker Platform have gas potential but have never been tested. The most likely pressure infiltration zones are the 11 - 1 3 sandstones located between 1500 and 2000'. Other sandstone zones above the top of grout at 5864' for well D-11 and 6925' for well 0-12 may also receive some infiltration. Sandstones packages 11 - 13 will probably have higher porosity and permeability than the deeper zone 31 measured ¡nthe Baker Platform area, according to geologic review. . ,. The proposed depth of wastewater disposal should provide an environmentally sound, long-term option for disposal of the secondary treated domestic wastewater from the Dillon platform. The proposed depth and location of disposal should isolate this wastewater from potable water supplies by much greater than 1 00'. The water quality of any impacted aquifers or saturated zones will probably be poor and since several aquifers exist at much less depth it is unlikely these deep aquifers will be used. In addition, this area has received a freshwater aquifer excemption for a ~ mile area beyond and laying directly below the Middle Ground Shoal Field (AOGCC AIO No.8). The water is expected to be highly saline and may contain natural petroleum. The proposed wastewater disposal volume is not significant relative to oil/gas/water production volumes from the offshore platform operations. Water supply wells along Cook Inlet occasionally have saltwater intrusion, and quality of the water sometimes makes it undesirable for consumption. The majority of potable water wells in the area are less than 300' deep, and we are not aware of any deeper than 500'. To the best of our knowledge, no water wells approach 1000', which is at least SOD' above the proposed disposal depth. Groundwater in the area is supplied mostly from unconsolidated quaternary sediments, which are reportedly 500 - 700' thick in the North Kenai area and thinner to the south. The uppermost unconfined aquifer supplies most private homes. The uppermost confined aquifer supplies many municipal and industrial wells as well as many private homes and is fairly well defined adjacent to coastline. General flow in local aquifers is toward Cook Inlet with both surface and sub-sea discharge to the inlet. The unconsolidated sediments may be 1000' or more feet thick in the Traâing Bay area and appear to be over 4000' thick in the Susitna Drainage. Sediment thickness in the remainder of Cook Inlet Basin generally is less than 1000' thick. With the proposed wastewat~r disposed below 1 SOD' at the Dillon Platform, significant strata should separate the disposal area from the unconsolidated sediments. -" ., 'e ee Unocal Dillon SAS Prapplication Conference March 1995 3 Mike Tauriainen. P.E. Consulting Engineers, Inc. Soldotna. AK 99669 Based on the presentation of this information at a preapplication conference, we believe that we can come to agreement with the Department as to what additional information will be required. Due to the nature of this project, not all submittal requirements of 18 AAC 72,220 have been included. Upon receiving your comments we will prepare a formal request for Approval to Construct with more detailed information. cc: Alice Bullington, Unocal Attachments: Well Logs Well Detail : J """95021 D 1=1 . WELL HEAD . : j ¡ .. . þ PRESSURE GAUGE ~" '. . . ~- 20" 00 . . > . , , BOTTOM OF COOK INLET -- .. 4 ¡ .. -- A . ~ '. A . .' ",4. , -I> - . . .'~' .. .- ......... . -' -- .4, . -- ... -.. 4 to : -.;. .. .. . j j \~ GROUT (TYP) 1.3 3/8" 00 ¡ / D- 12 WELL 1587' D-11 WELL 2001' j. 9 5/8n 00 .",$' .. TOP GROUT @ 0-12 WELL 6925' 0-1 WELL 5867' -".. :. ~.._../GROUT (TYP) .<:...~:. 'ø,' ,:' 4'" '4: -. - r 00 t NOTE: THIS DRAWING WAS PREPARED BASED ON INFORMATION SUPPLIED SY UNOCAL OIL CO. DILLON PLATFORM SAS SCAL£: 1":1' 35186 SPUR HWY. SOLDOTNA. AlASKA 99669 (907) 262-4624- FAX 262-5777 DATE: DRAWN: CHECKED: SCALE: PROJECT NO.: MARCH 1995 TS . HK AS SHOWN 95021 SHEET ¡}.:Ja[k@~!§ø CONSULTING ENGINEERS INC. DILLON PLATFORM SAS Of ---- -,.... . PUMP sÎ)I~:f : - -- ---' PuMP <Ç10P ~.... _0 ------f I , , , L/...A · I - - - - - - r- J : I I I I -'1 I I t-¡ljl'/lo I f ~ , , I " .. ,·1 ,.1)' I,..' ' ). C u RJ</; AI f OClMP TA N 1< CI!.Â/)< ?/jJ (fof?, 5 ,Ç.1J1i!Z&'r;. fJVMOs ~ J · 1 Ö ' if I,ffL§2..h.Ý: f I:!J._._~__ ~ I()~ l-.Æ..w;t~(LS..ið.&l.. s {(1 ~.,..,:11ðfN..._-:.e~_{,' f.c&Q..f!.$.I._w,/&.lic-£ iIJ2Q_Çr.J!..fJ......_~.__, . [t.m..:-$;~(1çtt.:1rÃ^t:_J-.j --..---.....-...--.. ;Ji.C.1I1;kA.L.../?U-ME.. J.&u.¡J_Md&/J ¡CA............__........ ':J I :1j.IML~L_fAk&ER .£lv· ----..-...---.--...--.--....--...- CRE"" Trlj furAP -- - --- -...... "- ~Eß~ \ swi ft. II I I I r / I / f f : I o 30 pPM ìR~T()l.l7é .è i c: i:f g - Š"~ c: :z aP1 ::J'~ ...J (;) C") I'V PJ 0 CQ ::s sn --- m. c..Þ C") C.D 0 Q1 3 e. CSJ CSJ õ' ~ ß\~(~ ;::0 ", n m - < fïi o .~ [XJ-N- .-- ðl £Eel -I tJft Po;; I I . I _-I I I l / ...... - - - ./ - e #6 .. " " . ~1l~uŒ a !A\~!A\~~b'~ ~ ALASIiA OIL.AND GAS / CONSERVATION COMMISSION / I 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501·3192 PHONE: (907) 279·1433 FAX: (907) 276-7542 TONYKNOWLE~GOVERNOR June 27, 1995 David Johnson, PE Environmental Engineer DEC, Kenai District Office 35390 K-Beach Road, Suite 11 Soldotna, AI< 99669 Re: ·b~~fQ~~r.~~Mr~Wií'é~~~ º.2.~J)~s.:tifi'al~1PÐìifóìtWêlIs, d~;"'.'~~'·~~.,;!!f.:;f~~,:t<;~~:~:~~~';;~";,~:;..",~;';'f;t~",·:1 C3'j r Dear Mr. Johnson: We have analyzed the package of information furnished to us regarding the disposal of domestic waste water from platform Dillon in the annuli of two wells, Nos. 11 and 12. We have two coriunents which are listed below. 1. The rreshwater exemption for Cook Inlet was not granted by the AOGCC; it was granted by EPA prior to our taking primacy of the UIC Class II program. 2. We support UNOCAL's proposal and encourage your approval. Ifwe can be of help, please contact me at 279-1433. cc: Blair WondzelI tì {; #5 .. '. , . -- ( , " MEMORANDUM State of Alaska Alaska Oil & Gas Conservation Commission Date: 22Jun95 To: David Johnston File: cumgsdww.mem ~6/2.3 Fm: Blair Wondzell Subj: Annulus Disposal of Domestic Waste Water, MGS, Dillon Platform As you requested, I read and analyzed the package of information sent to you by Mike Tauriainen, regarding UNOCAL's request to dispose of domestic waste water down the surface casing/production casing annuli of two MGS Platform Dillon wells, Dillon 11 and Dillon 12. My comments are stated below. 1. Since we will be taking over "annulus pumping" and this may come under that description, I'm pleased to see DEC setting this precedent. 2. DEC's Kenai District Office states that the Cook Inlet fresh water exemption was granted by the AOGCC. This is in error, the exemption was granted by EPA prior to our taking over primacy of the Class II part of the UIC program. 3. The "Coastal Project Questionnaire and Certification Statement" contains the "Start Date" as "Summer 1995" and the "End Date" as "Summer 1995". (UNOCAL's Alice Bullington says that's an error, end date should be "platform abandonment"). 4. Data presented on Dillon well no. 11 discloses that the surface casing is set at 2001' and that casing holes at 2330 were squeezed; the annulus may not be open. UNOCAL is checking on this possibility. Attached is a draft letter to DEC in Kenai that you may want to send. r ".-<' #4 i'{~O sr"l": V'" t'.s- ,.".~ 0 ~ -. %. ~ ~~ r5 o ~ \ ~ <"", ....,0 l''''L PRO~~v U.S.'VIRONMENTAL PROTECTION AGICY REGION 10 1200 SIXTH AVENUE SEATTLE. WASHINGTON 98101 NÐV ~1986 REPLY TO ATìN OF MIS 409 W. G. Smith, District Manager Amoco Production Company P.O. Box 100779 Anchorage, Alaska 99510 RE: Termination of EPA Rule Authorization for Injection Wells Dear Mr. Smith: The Alaska Oil and Gas Conservation Commission issued the Amoco Production Company Areatnject.1".Orders No. 6 for the Northern Portion of Granite Point Field (Platforms Anna and Bruce) and No.7 for the Northern Portion of Middle Ground Shoal Field (Platform Baker) and No. 8 for the Southern Portion of Middle Ground Shoal Field (Platform Dillon) on September 4, 1986. Therefore, the EPA rule authorization under either 40 CFR 144.21 or 40 CFR 144.22 for existing injection wells is terminated. Sincerely, ¡L¿J:.~J Robert S. Burd Director, Water Division cc: C. V. Chatterton, AOGCC r\~r'¡ ,- r:~:l~ ,.... .., ~ ,... "I:"', ,~. I" ( .... 7' ...-., .> "- '-' - 4~2.S1\é; o¡: ð: G2S Cons; Cùrn:ïI!Ss:U: An~hc:~2rr ·f . #3 , "T~ AMOCO ~I~ I I ~ V~\ \ II -dc...:.t Å{ :-1(, " "l'-QtJ. I. I j..\\ DI'7ì' WI /".3.! ~\...i. s:;."..,... :..... '2' .....""\<'>. ofd'. 1° ,i.:;! ~C:. ~ ()OMM Amoco Production Company COM~¡1 Post Office Box 100779 cCi/rA Anchorage. Alaska 99510 fF:::? ENG 907-272-8471 ~:~n ['I,)\j- mlENG [:i'·JG- ....---- \ ,#, '" W. G. Smith District Manager October 6, 1986 File: FEW-251-986.511 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Allchorage, Alaska 99501 Area Injection Order No.6, Northern Portion of Granite Point Field Area Injection Order No.7, Northern Portion of Middle Ground Shoal Field Are. Injøa_iO'*rlo. 8, Southern Portion of Middle Ground Shoal Field Referencing our letter of September 30, 1986, File: FEW-232-986.511 and telecon between M. T. Minder and J. C. Blagg on October 3, 1986, we are re-submitting our proposed schedule for testing the mechanical integrity of the tubing/casing annulus on our water injection wells. The primary difference in scheduling is that we will now test each well at this tinle in order to obtain IIbaselinell surveys rather than test each well individually when its previous test becomes four years old. As with our earlier proposed schedule, each well will then be retested at least once every four years. For ease of operation, retesting on a per platform basis by the following schedule is suggested: Year Platform 1987 Baker 1988 Anna 1989 Di 11 on 1990 Bruce Tests will be updated every fourth year ther'eafter. Attached is our proposed test procedure and a listing by platform all injection wells with their respective packer setting depth, required annulus test pressure, and relative comments. kECEIVED OCT 1 0 1986 Alaska 011 & Gas Cons. Commission Anchorage ( to) \. I , w . C. V. Chatterton, Chairman FEW-251-986.511 October 6, 1986 Page 2 We will begin the annulus pressure tests as soon as possible following approval of our program. Please direct any questions to Jeff Blagg__at 562-2147. Very truly yours, ø~ W. G. Smith District Manager cc: S. W. Souders M. E. Siekawitch JCB/ j r 117/jcb1 RECEIVED OCT 1 0 1986 Alask! 011 & 0:15 Cons. Commission AnC~1~f~q! #2 ,4fr;sJ6::$:' .c;OMM j.. .JA~ ;l1.J,-?f¡ µ-.COMM -..P" '¥ Øf1,yvo. PI~, ¡,..It j~f!' 'i3/"-j~ COMM----r: Amoco Production Compa . 1ES ENG I Post Office Box 100779 81"-1 r.: \18. I Anchorage, Alaska 99510 "Fl r-r 1" 907-272-8471 ,.J c \\.::1 I s,~ ,;1j tf 7 ~:'~i-~~t:ÖL I C'R (.'....'.". _:'.'_,__.~.:~::U~_ , .~~fC~ ASSm ~!'J£:'f\SST- r ~!_þ.TrEcHI STATTECR FILE: / c1. , W. G. Smith District Manager September 30, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Conmi ss i on File: FEW-232-986.511 Area Injection Order No.6, Northern Portion of Granite Point Field Area Injection Order No.7, Northern Portion of Middle Ground Shoal Field Area'lnfØ;t1Øft Order", 8, Southern Portion of Middle Ground Shoal Field Regarding Rule 6 of the captioned Area Injection Orders, Amoco Production Company is required to develop and coordinate with the COITmission a schedule for testing the mechanical integrity on each water injection well tubing/casing annulus. We presently have active four water injection wells with completions four years old or older, and we propose renewing the tubing/casing annulus pressure test on these wells by December 31, 1986. Our other water injection wells will be tested when the existing completion becomes four years old or following repair work, and every fourth year thereafter. Please see the attached Tables 1-4 which list by platform our water injection wells and the date of the next tubing/casing annulus pressure test. Also attached is our proposed tubing/casing annulus test procedure. Please direct any technical questions you might have to Jeff Blagg at 562-2147. j!.-1; iú : ('",.1) 'J...-t V"1'1 Very truly yours, ;: 7 //~j/ tf/'h/- 1ó/1'/8'? ~iS~~i~~i~~r kXF/~/N~) /711'Í p;¿"J' ie, xrt lie I} ~A,J ik I· ,L JCB/dds ,..¡t;~t: WI ')1$ MIIA/"j""þ;1I/T Attachments _jB~0-_~,4t,l..?IfÐpt)"Jf /. I . S W 1 I¿'II~ C1 I. I J"" 1.1 0 . cc. . .. Qltt::rl~ Kif -r-O!t w . M. E. I WLL "'0 .) . J. . rTI\. .... MM,Aµ,(If.TlPN - 1.t:J,fYt"t.¡t/'Q, 10. t'tI " 3 /) /' .¡ ;¡"4I t: ,\\NIµJ W"))s c...'Þ/~f)rt"/l1"itI~J.r Pltbhs __.~"! iNj.!-é"ItI~'_~~d,~t!~!!1I:J/..~t . WA¡liNj ðH ¡:¡,./i,~~~ r Ct). AfF1tb.J:a--- tlflNÞ, :Jt /3 C~ co/l"'f'61C P. \.-Jrtt.. p~ob.g j~j iNi() R"~lrf UNI::S I. ADc;{'(' ";"lteJ .If P......t( N#.;¿, ~ at. .;.... j},'~ b~1~ h^~ /111 í 0.-. _~.~ e..ýl~ fl~ .:-¡. ~ b. 1'1' 1.,1 ''fr'¡( 1.6"'./. elf....J), I G(:~~~~~i/{ì1 ¡:~~~"~~. c. .y 'P.... s~. f~~1 r",," ,¿j þ: , z.ç cf"-;'f~ "'" /5·"''' (hAVE .."""".niQ", ...~I...') 2, L,J.: ~,..J.. 'Z. '> 7" ,f !.-í~<t;....~(t.¡\ 0-.0- <) I wi 'I $J.-.~t.,.\ r.... w.o, tv 1.."\ <h->. ~~: /tJ~..1 ...,.-< f I..., """ " "t k"... ~ w-"O. :: Anchorage ··.._v..'" f") #1 þ~ , , W. G. Smith District Manager August 29, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ¡Hð ¡./tl5.~l?f8 File: FEW-220-986.511 Supplemental Data on Waste Disposal Horizons Area Injection Order Applications Middle Ground Shoal and Granite Point Fields In reference to our applications for Area Injection Orders, Platforms Baker and Dillon at the Middle Ground Shoal Field, and Platforms Anna and Bruce atthe Granite Point Field, the attached supplemental data concern- ing horizons for waste disposal is submitted for your consideration. Please contact Mr. Jeff Blagg or Mr. Fred White at 562-2147 if you have questions or require additional information. . t.:~..>~{1O Sincerely, -~".~~":; ø~ !!'i.!?-i': W. G. Smith District Manager JCB/dds Attachments 108/jcbl iíl ,,~ ,;" RECE\V£D SEP04- comm\sston , k8 011 & Gas Cons. A as Anchorage ...;,. p,. + + .- TI ., ~ Z4 g; ~..Q N1 I + + I Zb 25 H + + 20 + + ZCJ 30 + + I + + 3S 36 I 31 32 -.tDL f7SQS RI3w R /2. IN --- -----r -. 0 lD L..W c::<:> ~ (,--) <3:1 -.~ c: r-;.-; ! ."""...-' 0 è:3 ..;;t. <.:> '- I -~ 0 L.U N if> .s= , c-:S ;::..') c::: ......l ¡", «. 1..0'1·.".1 :::J o<S -, 0::: õ ~ rn CI:I <t -- I {- ¡UJlIIII I ~ SOUTH MIDDLE GROUND SHOAL FIELD I 3 2. + + + 10 II 12- ADL /8754 + + + /5 14 + + + 22 2.3 2.4 + + + UJUIII27 26 25 :::: ADL /8756 - - ~ ªª1111111~1111111111111111'IJllllllL - - :: ADL 18746 = - - - = 3'-1 - - - - - - - --- - - - - - - - - - - - - - - - - --- - - - - - - - fßmllllo wum-If 35 -- - - - - - - - --- - - - - - - 3 2. + - - - - - iIlIlIIl~ - - - - ~ + - - - - - - - - ffi 11I11 ~ + /5 /'1 + + + 6 + 7 + 13 T 18 B N + /4 + 30 + 36 31 --- 6 + /2 '7 / 13 T 7 N + Amoco Production Company FIGURE A . . SECTION B PLAT 20 AAC 25.402 (c) (1) 20 AAC 25.252 (c) (1) Figure B is a plat showing the location of all wells that penetrate the uppermost injection zone within the SMGS Lease ADL-18746 boundary. _,u.,··~"",", ...... .-,. .........., -- --1'---- i I 3Lf T\ 81 ---~ T ~I \ \ I 3 I I ! ~¡ I ~---~- ~ \ 10 . 2 -.- -,- 13 . 3 . 14 . 8 8RD -t- . 4 . 2RD . 6 . 7 . 5 . LN- Â C¡ RD Å 35 II. -- 2 . I·· ._,_ _____d_.~_ __.....n_......_.~ ,.__ I' I +- I I I I I I I I I I~- I I I I I I I I C + R 13V1 ---- - -- Amoco Production Company . I , SOUTH MIDDLE GROUND SHOAL FIELD FIGURE B I -..-.....- --- -- - ,--- - -- - + , ) . . SECTION C OPERATORS/SURFACE OWNERS 20 AAC 25.402 (c)(2) 20 AAC 25.252 (c)(2) The surface owners and operators within the area of this Area Injection Order and extending 1/4 mile beyond the boundary (excluding Amoco Produc- tion Company) are: * State of Alaska Oepartment of Natural Resources 3601 C Street Anchorage, Alaska 99503 Shell Western E and P, Inc. 601 West Fifth Avenue Suite 810 Anchorage, Alaska 99501 * . See attached affidavit . SECTION 0 AFF IDA V IT 20 AAC 25.402 (c)(3) 20 AAC 25.252 (c)(3) . . AFFIDAVIT STATE OF ALASKA THIRD JUDICIAL DISTRICT Jeffrey C. Blagg, being first duly sworn on oath, deposes and says: That I am an employee of Amoco Production Company. That on the n2( day of July, 1986, I caused to be mailed a true and correct copy of this applica- tion to the following operators and surface owners listed in Section C: Mr. Jim Eason, Acting Director Division of Oil and Gas State of Alaska Department of Natural Resources P.O. Box 7034 Anchorage, Alaska 99510-0734 Mr. M. L. Woodson Shell Western E and P, Inc. 601 West Fifth Avenue Suite 810 Anchorage, Alaska 99501 . . by placing a said copy in the United States Mail with postage prepaid and certified at Anchorage, Alaska. SUBSCRIBED AND SWORN to before me this ~\ ~ day of July, 1986. ~±:k~, ¥-,mL~~ No ry Public in and for Alaska. ,¡,j CC;-lm;ssion Expires; My commi ss i on expi res May 2, 1987. ~ . . SECTION E DESCRIPTION OF OPERATION 20 AAC 25.402(c)(4) Current and proposed injection operations at SMGS Lease ADL-18746 are divided into two broad categories: enhanced recovery and fluid disposal. Enhanced recovery injection wells are used for the introduction of dis- placing fluids into the reservoir to increase the ultimate recovery of oil. Currently, water injection is the only method of enhanced recovery in use at SMGS Lease 18746. The injection system utilizes Cook Inlet sea water passed through a network of filters, piping, injection pumps, and manifolding. Future injections may incorporate the injection of produced formation water or polymers. Existing water injection wells and future injection wells will continue to be designed, constructed, operated, and monitored to ensure the injection fluid is entering the oil reservoir. Enhanced oil recovery methods are/will be confined to Tertiary age for- mations. Presently, there are no disposal wells used for the disposal of produced water or other non-hazardous waste fluids generated during normal drill- ing, workover, or production operations. Future disposal wells for injecting these waste products will be designed, constructed, operated, and monitored to ensure the injected fluid is confined to the injection zone. Waste disposal will be confined to Tertiary age formations. . . SECTION F POOL INFORMATION 20 AAC 25.402 (c)(5) The South pools affected by injection for enhanced recovery and waste disposal are defined by Rule 2 of Conservation Order No. 44 as the following measured depth intervals in the Pan American Corporation State 17595 No.4 Well: MGS 0 il Pool A - 5300' to 5720' MGS Oil Pool B - 5720' to 6100' MGS Oil Pool C - 6100' to 6400' MGS Oi 1 Pool o - 6400' to 6750' MGS Oil Pool E - 67501 to 7050' MGS Oil Pool F - 70501 to 7375' MGS Oi 1 Pool G - 73751 to 92151 . . SECTION G GEOLOGIC INFORMATION 20 AAC 25.402 (c)(6) 20 AAC 25.252(c)(4) The South Middle Ground Shoal anticline is a long, extremely narrow anticlinal feature which strikes north 10° east on the northern portion. The field is located at the crest of the anticline. The east flank dips from 33°E near the crest to 69°E at the extreme east flank in 17595 No.9. The west flank dips between 55-800W as implied by the 17595 No.8. Depositional patterns in South Middle Ground Shoal indicate that the anticline did not exist during Oligocene to Miocene deposition. This is illustrated by the lack of thin or bald spots along the crest of the anticline in the depositional patterns. Although sand thickness within each Tyonek zone varies a great deal, pore thicknesses are very similar within each zone. Sands are generally thicker to the north and east but the best reservoir tends to be east and southeast. The Tyonek C and D sand members include units designated by the State of Alaska as Middle Ground Shoal (MGS) A through F as shown on Figure G. The A sand is an alluvial sandstone, coal, and flood-plain shale. The BCD is a fill channel deposit. The E and F are estuarine flood plain siltstones, shales and coals. The Miocene Tyonek C sands are composed of quartzitic, matrix supported conglomeratic sandstones, interbedded with siltstones, shales and coals. These beds were deposited by braided streams, migrating across the width of their flood plains. The E and F zones represent a transgressive phase with siltier sands. The best quality reservoir occurs to the northeast and southwest in the F zone. The best reservoir was deposited to the east and southeast during A through E time. Sands are thicker to the northeast only during the depo- sition of C and A sands. The A and BCD interval represents a regressive braided stream environment. The best qual ity sand was deposited on strike over the eastern flank of the field. The Oligocene Hemlock conglomerate is the main reservior of the South Middle Ground Shoal Field. This alluvial conglomerate is composed of clast supported conglomerate interbedded with siltstone, sandstone and clays. This conglomerate was deposited by braided stream channels of low to moderate gradient flowing from the north and west. The Hemlock is composed of subrounded moderately sorted quartz, black chert pebbles and . . metamorphic rock fragments. This unit was deposted uncomformably over the West Foreland. The Hemlock and the overlying Tyonek section pinchout to the east on the Kenai Peninsula. The Hemlock G sands and conglomerates were deposited by braided streams shifting across their flood plain. These conglomerates have a good matrix porosity four to 15 percent and a permeability of only 2.1 md is needed for production. Extensive deposition occurred during G-3, G-4 and G-5 time. Depositional strike was north-south. During G-5 time highest sand deposition occurred along what is now the crest of the anticline. Deposition shifted north and eastward in G-4 time and the northern deposition shifted westward in G-3 time. These sands are very well developed to the north, south, and southeast of Platform Baker. The South Middle Ground Shoal area was flooded at the end of G-3 time and a low energy environment existed north of the present location of the platform. The G-2 sand tends to be a tighter sand with average porosity only four to eight percent. The G-l represents a regressive environment of braided stream deposition. Though not as thick as the G-3, G-4 or G-5, this sand is very porous especially north, east and southeast of Baker platform. The EFG sand has an average net pay thickness of 330 feet, porosity of 11 percent, and permeability of 5.4 md. The confining zones between and above producing units are a series of tight, impermeable siltstones and shales, varying in thickness from 50 t.o 200 feet. . . FIGURE G tit. AT&. '. ~o "LV COOK INLET TERTIARY NOMENCLATURE Hun AGE ~IUiH PHT, ROCK UNITS SUITES PLEISTO.. CENE Glacial cover , I H If t- , . ,led. PLIOCENE Bishop Creel-: mbr. H TJ er- Sterling Fm. st.. . Cook Inlet sand m'br. ~ð ;6"- E,it'l. Beluga Fm. 5 W es t For x m b r. ? . ~. c... Chuitna m b r. '6 235 ~ 0 S.TATE ~ c: "A t' san d m b r. M IOCEN E A 2 33 Co:) PRODUCING ,~ - NO M ENCLATU.R E . c::: :z "8 ., sand m b r, MIDDLE GROU~ u..¡ Tyonek Fm. :x: \.--- SHOAL "C " sa n d m b r. "¡" , . 6 "3" "C" "D" sand m b r. -"0"' "f' . £1 3 13 "'í" ~<v e,i.ote "ý" v~ \>0 Gilut H em lock Conglomerate 6 V 0 333 374 .6. West Foreland Fm. ~. Tsadaka m br, I EOCENE I : Wishbone Fm'. PALEO- CENE Chickaloon C~ . ì'.. SHut I UPPER CRET- Matanuska Fm. ACEOUS U P, PER Naknek Fm. JURASSIC feu n IA·I' WM CO/'/NH~Y AP~L.1977 . . ._~....... ..\1__~"'~·""~~" ,........ 'JI\~~..""'--.""" _. .... . . . SECTION H WELL LOGS 20 AAC 25.402 (c)(7) 20 AAC 25.252 (c)(5) All open hole logs from SMGS Lease ADL-18746 are sent to the commission as the logs are completed. . . SECTION I CASING INFORMATION 20 AAC 25.402(c)(8) 20 AAC 25.252(c)(6) Typical SMGS Lease ADL-18746 injection wells are cased as shown in Figure I. All newly completed injection wells will be cased, cemented, and tested in accordance with 20 AAC 25.252. Casing design wi 11 be submitted for approval as required under 20 AAC 25.005 (Form 10-401) on the drilling permit application. In wells converted to injection, the casing will be retested in accordance with 20 AAC 25.412(c), and the well will be completed in accordance with 20 AAC 25.412(d). . " 3!:2- TvßINCr o.M(j( PAC.KEf<. TE.5 TED To 4000 PSI . . FIGURE I . WELLHEAD SËA LEVEL MUD LINE N I L.JO PILE @ 200 20// CONDUc...TOt<. @ bOO~ 133/8 // SUP,FAG~ Cf\-::'IN& @ ZOoo / // q ~ Ir-JíEIZMEt)IATE CASING @. ToP OF J-Ú;::MLOCk "<":7-- 7" LINE1'\.. @ BA~f" OF H£MLOc...K. "(7" , '.I . . SECTION J INJECTION FLUID COMPOSITION INJECTION RATE AND PRESSURE 20 AAC 25.402 (c)(9) & (10) 20 AAC 25.252(c)(7) & (8) Enhanced Recovery Fluids The type of fluid injected into enhance recovery injection wells is fil- tered, treated Cook Inlet sea water. Water treatment additives include biocide, corrosion inhibitors, scale inhibitors, and oxygen scavengers. The maximum expected injection rate on a field wide basis is 15 MBWPD, and on a per well basis is 6 MBWPD. Water sensitivity tests on core samples showed no significant problems with formation plugging or clay swelling caused by injecting Cook Inlet sea water. The maximum wellhead injection pressure for enhanced recovery injection wells at SMGS Lease ADL-18746 is 4000 psig. This pressure is the maximum discharge pressure of the injection equipment. The average injection pressure is estimated to be 3800 psig. Fluid Disposal The injection fluid for disposal is expected to be predominantly drilling, workover, and production related waste fluids. The injection stream could include drilling mud, reserve pit water, contaminated crude, diesel gel, glycol, domestic waste water and workover fluids. There are presently no waste disposal wells on SMGS Lease 18746. The maximum expected injection rate on a per well basis is 6000 BPD. The maximum expected wellhead pressure for fluid disposal wells is 4000 psig. The average injection pressure will be determined at such time that a well is converted to waste disposal. / : ·. . SECTION K FRACTURE INFORMATION 20 AAC 25.402(c)(11) 20 AAC 25.252(c)(9) The proposed maximum injection pressure for the enhanced recovery and fluid disposal wells will not initiate fractures in the confining strata which might enable the injection or formation fluid to enter freshwater strata. Enhanced Recovery The Hemlock State "G" Conglom rate has a fracture gradient of 0.9 to 1.1 psi/ft. A fracture gradient f 0.9 psi/ft corresponds to a bottom hole injection fracture pressure of 8280 psig. The surface injection pressure is estimated to average 3800 sig with a maximum projected pressure of 4000 psig. Since startup of waterfloodi g at SMGS Lease ADL-18746, injection surveillance data has been co lected. Such data has included injection profiles, temperature surveys, injectivity index monitoring, pressure fall off, and step rate tests. T is information has verified that water injections have not extended i to freshwater zones. Fluid Disposal Injection zones for fluid dis osal may exhibit some hydraulic fracturing within the injection horizon a ound the wellbore because of the nature of the disposal fluids and the p tential for high solids content. At such time that a well is converted 0 fluid disposal, step rate testing will be performed on the Tertiary inj ction interval to determine the fracture gradient. If the fracture gr dient must be exceeded to inject fluids, then additional testing will e performed to ensure that injection or formation fluid will not enter nonexempt freshwater strata. i' . . SECTION L FORMATION FLUID 20 AAC 25.402(c)(12) 20 AAC 25.252(c)(10) A water analysis for the Tertiary State "A" is presented as figure L-l. A water analysis for the Tertiary State "BCD" is presented as Figure L-2. A water analysis for the Tertiary State "EFG" is presented as Figure L-3. . . FIGURE L-l CL1-12A (R~. ".0. IIOX 2127 . ANCliOR,AGt. ALA.teA . CMŒMICAL&. . G~OLOGICAL LABORATORIES À',UIUCANSTRA TIGUAPHIC COMPANY ~.., ",.<-/ WATER ANALYSIS REPORT O?!!TIATOR W~LL UO FIELD COUNTY STATR. Pan American Petroleum Corp. MGS 11-S 17595 Middle Ground Shoal LAB NO A-630-1 T-8-N, R-13-W, SM. Alaska DATR. August 14, 1970 LOCATION. NE SE Sec. 35, FORMATION A Zone INTERVAl. SAUPL& PROU REMARKS li:: CONCLUSIONS' Sample taken August 6, 1970. C:o.thns .!!:Q! m~/l Anions mtr/1 ~ Sod.!um 3382 147.10 Salfate 4 0.08 Pot:=.imn 12 0.31 Chlorid. -. - - - 3270 92.21 C¿cium 7 0.35 Carbonate 396 13.19 !::!4~cciu:n 4 0.33 Bicarbo=~ 2598 42.61 lro:1 Hydrozide C ~) TotIIJ Catioca - 148.09 Total An10na 148.09 - - - - Tot:cl ~lved aolid.. mVl 8355 Specific rœiatance @ MOP.: N.Cl OÇ. ci \r.Ù=t. m¡¡/l 7880 Oboerved 0.838 obm-~ Obc=vcd pH - - - - - 8.3 c.lc"''tw - - - - 0.83 ohm-~ WATER ANALYSIS PATTERN Scala MEQ per Unit Sample above described N¡¡ Cl 50 Na Ca HC03 5 Ca Mg SO... 5 Mg Fe CO 31 5 Fe (- CO. Cl HC031 SO~ (N. ....... ._ crepbo Iadu4.o No. I(, ... 1.1) NOTE: Mc/I=WllIicromo po< Ut... Jloq/I= lliU1ç.... oquh-.l.o.. po< U_ So4"'- chIori4. oq..¡"aIoa.=~ Dual.;> .t H..-Ioo.... ~ ~ __.. .. .,',. .~. .-" . .... '."j..... " A .,. "~'1.: ?''',:-: . . . . .~ : 'j! '0f-:' ~:-: -. ;" ~:.~~'~~ ~ r;t ¡ 'u" t . 1;;,.~; '" ( ~;. .~. ~."'.~\;~> ')nd·]· , i' . F< L" L. i" t~',i.~ , - L: , !'.:~ . ¡.- . . , !> L t ~',:" I;., ~.. . ¡i r..; t·".: I:" II;:. :.:., , - ..~ ,. I' I f: , I: f> V ì ( , I !. ~: " ~:.~.: l" L<' t "": ".-.. f··,~. h I:' t!":; , ,,".' " f·;- [;,.: ! . .:~..~. - :r.-" -'\'~" f.:··'; . . ;:~. !: to"~ . , I : ¡. i t ,. ¡ , {" F L t" . " . CLt-12" (m!V. '.0j' ~¡ I ~ ~ . FIGURE L-2 CHEMICAL & GEOLOGICAL LABORATORIES AMERICAN.5TRATIGI1IAPHIC COMPANY< (~.) P.O. 110M. 212'7 . ANCHOftAG~ At.AA1CA . WATER ANALYSIS REPORT OP:;:~r_TO:l Vni:LI. ~Q FIELD COUNTY STAT'" Pan American Petroleum Corp. MGS 11-1 17595 Middle Ground Shoal DATtt August 14, 1970 LOCATION. NE SE Sec. FORMATION B. C & D INTERV A T SAMPLE FROU LAB NO A-631-2 35. T-8-N. R-13-W. SM. Zone Alaska P3=.1J..~U~S ~ CONCLUSIONS' . . Sample taken August 5. 1970. C::é¢'"~ m,\/l ~ ~ m~/l ~ Scili= - . - - 3348 145.61 SulfAte - - - - 18 0.37 Po~= - - - - - 32 0.95 Ch1orid. -. - - - - - 3210 90.52 Ca.!::i= - - - . - 13 0.65 Cöu-bonate 396 13.19 - !.:2~am - - - - 6 0.49 BicArbonate 2660 43.62 - Iraa Hydroxide - - - - - ( 147.70 147.70 Tab! C.,rio:1a - - . - Total An10na - - - - Totù <fu:301ve<! &O~ mVl 8333 Specific reciatanc. @ 68eF.: N~Cl oquiv.cl=t. 1Dt/1 7841 O~ed 0.848 obm-a.tua Obc&ve..i pH . - - - . 8.2 Calculated . - - - 0,85 ohm-~ WATER ANALYSIS PATTERN Sale MEQ per Unit S=ple above described Na ....,.... -to'¿ -4.- ~" C~ Mg Fe ( Cl 50 Na Cl HC03 5 Ca HC03 SO.. 5 Mg SO" CO.' 5 Fe CO. .~\ r' '1 Q\ 0'1 ,¡ . , ,. ., ., \,;1 -....,.,.,_ .¡,..... j~".. 4 (M.. 'NN. '" ..- ....ça.. L.cJ.- N... JC. ... 1(1) !lOTK: Mc/I::J.101i.......... p.- U,« ."VI=: 1fW1cne "'Iw..aleau pel' U_ !:odhu. chIori4. ..w.v-,=~ D..,.. a H......_ .-IcuiMlo.. (.- _u \) ,....'!... ._,~~_.. ...,,:,,"!, -' >1" ·.·-T'~.~f':~."·· -.4,..,.,.,.¡ ...., ..... .,f . ;- .!..:~:~.~':~;..-. --:.: ~ .'."1 .. ~ -:. .....-..."' .:- .-; .. . !<~ ·-r .. b~· ¡:'~ t?- ~~:. . i:~ i:- . ' ¡:::- L. ¡: . i'.: .' i,·, ~ .. h t ," t-"t.. t'" I' ::~~ '" I,:,. t-, p: l':r' I·: ..·t' t ~.-: I· f~( f" .. ~:.. . f,};" ¡> 1-. j f- . Î h- I' :. I' ¡: '. ~ ~:. . f:.r.- f' .,'~ r: tr".·.?···'.·.··' ~". . I;~ . ~,._: t:;·: ,~'. t·.;l;~: ., ...... . ~ ..': 1-'. t,~·, r' t ~. f:' [. '.." .... r t~t~ t,.. ., .~ \~;~~?fl~ ....- : -,.;.~ ~ ·' CLi-12.\ (:'~<:V. 12\34) . FIGUREL-3 fr' ,". CHF.M~CAT, &. ~F.OI,OGrCAL lÄBôllXfô'RÏË§ /: \- R \"n í't; AJ ! 1 " '.J'] 8 Â ~ '. i"Q_ a ~~}~ ßm,uue:lU:1 Z'lC:U\i2Gf2APMIC COMPANY ".0.50)( 2U1' . AN-CHORA.GE. ALASKA .. O??lTI:A70l~~::.~·Y>i (';-.-,",\ P;-::-·+,'""nl P1'~ '\VL-:LL ¡·¡o._~L~.¿;.~~~~q~~ (II) Co-r:-~... VIATER ANALYSIS REPORT LAB NO J.?I:i.-::LD____2~~··...,-: "¡,,,-_-2.J:-i 1l""i~ COü!':7"'r zr¡ :.\7-:;" t. -; ::-, '_-:\"~ :--2Ii}"....Ä¡:~3 Q CO~~¡CLUSIO~¡Ð.. 1~~Jdr1-:r --:._T::-.~·.';"l"* DATi!: ·hn!~_.J> 1 q69 LOÇATI01"¡ I·l~·: ~)~;: .'3f:c. I;:¡?.. í!,. {~. A-2?~'-? 1C;.. "T' _p_:: , Î~~._"'4 1-".-;} Ccnzl O:T!F":1""'·gti~:: c..:..... ., FORMATION INTERV A r SAMPLE FROM Lonrr ;3trj.ng ~'i::.h+ly ""lr-"·";r ï~~~;""t -:T~~1101.! f~ltrnT.n \.;-:-,:'~.:~'}.:::'-:·r:s ~"¡~.:" ~_ ':" ¡'"". f: ... '", S:1ndG 4~~ t.~j_ c; f;'81ò. C::~c-;;.~ 12:fJ... E!;;..~ Anion.~ m'Jll 2ß 29hS 16 '/:::r:::<l/1 --'- ;:cÆ~:-a ~~l 0.('j ;n 1 ;~, iI R2 ?~t$.:1iic..;--:l 0.77 O.L() ("V)S' C--..J..::: ~::'-o. ¡..~ :"~';..2l7-;::~~4 '< "';':"~.::J. - 2-b.:i2:~ ,j ~ ~ 1 ~6..;)h ~¡c~ C¡,¡¡tJ.·;:y.::.z Specific n:.~tt:.m:o G œop,: O~rvcd o:::':>~c:; obm-l~~ "7 ~r}.'~ i. 0~ (~~"03r¡(":d iN::'::J~ L:l::ill r·~.::.Cl '::::'Uh1~J~tJ r:-.:;/l f;QC};: I~ ? 00-.;.G('",j'':-.j p:-r o..~ß 8,~OL) 1.20 ::;I"hl SulIZlte cro.oridll C<:.:-OOIUi te ~<J .,~ ... ' Bk~bo:J;z.t,;, lì J,, Hydro..jdc T ct."'.1 :...WCf1lt¡ ] ~(,. ?)¡ 0. ex) O.9? Cclc\.1h.tc.:J. V/J."o.TER ANALYSIS PATTERN S:l;j¡~}C ~bovc d":3cnbc:d N" ~~,m~;'~~~~~ì. C¡ L:. r~;- '"!....4o '"-'-___,__...........t..:..u <'--t +- .-..._........._LrLrrf·¡....j.+.....·~Æ:¡:"f-,,-I ~~-,..-.-'-.--I-~-'.~~-. -, ~ . ~...~ L.. L¡<_;t ....i-I-·....·~·r-~r:-f-~..JJ.I-Jo 11'·"'I~·.J \._ .__:__o-:.~. ....J.._-,_...,... 4..........I.··-..,·_,.........··....L..yr I..........-I·.L~· -r-.:¡"'-.f b:~~:f-h~~J:l::~.!_:.::~~t1~¡.;t:t:::-~.·. ~~+-¡¡ :p+t; C~l ~.~E::::.;:--..:;...~~~_~_lx;.;t:...'"7J±.~~.;..;~jjJ. ,;;~".LJ. -++t~ HC03 .... ~:.I.-: ~--t""''' ~...........~.- ;-..-........-...._.:f--,-1 ~......-.;.-+. 1 ·;-t""tt...+-L."-4t--ti . '::!illl'ifi::~ p~ -,..-' .~J-'·1 "0"'-'." c'- L."~.¡-:-,~....c.:::r::ì.!t 1~...tJ~t.tj:J' ~mf~~m1 :fll~~~~~llig~Hnmt:Hf!~i~ J \. l S~l~ MEQ per Unìt Cl (J" Na .)u 5 Ca 5 Mg 5 HC03 S04 co;, (H. ....;U4 i-n at,..QI"r. c-r.øh. iw.dud.,.. N6.. -r:.. &Ad U) N07:~: ¡"¡~/l;:,..=~Ct}:;T_CfI ;'"011' tfet I4"'Vt=:; }.í¡m~T.(¡\ vqf,U;Y4.1.7\t. p4.( Shw O,.;"j'",,,-'t cM.:.ïná .q~l..,...J.¡,..t=by Dv~ ~ l¡.~èCl'.1DII CiI.~tÎQn. hoa. c~u. 700'1· - -._-_..-,,~. _.._--~._---_._" . . SECTION M Aquifer Exemption 20 AAC 25.402(c)(13) 20 AAC 25.252(c)(11) The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the South Middle Ground Shoal Field are exempted aquifers for Class II injection. (Reference 40 CFR 147.102(b)(2) and 20 AAC 25.440(c).) ~ · .. SECTION N HYDROCARBON RECOVERY 20 AAC 25.402(c)(14) Incremental hydrocarbon recovery from the South Middle Ground Shoal Field, Platform Dillon, resulting from enhanced recovery waterflood operations is 15.6 MMBO. . . SECTION 0 MECHANICAL INTEGRITY 20 AAC 25.402(d) and (e) 20 AAC 25.252(d) and (e) In newly drilled South Middle Ground Shoal injection wells, the casing is pressure tested in accordance with 20 AAC 25.030(g). If a producing well is converted to injection, the casing pressure test will be repeated in accordance with 20 AAC 25.412 (c), prior to injection. Thereafter, casing-tubing annulus pressures will be monitored on a regular basis and reported monthly on Form 10-406 in accordance with 20 AAC 25.402(d). All injection wells will be constructed in compliance with mechanical integrity criteria as set forth in 20 AAC 25.252(d) and 20 AAC 25.402(d). 20 AAC 25.402(e) requires immediate notice to the Commission and correc- tive action if the casing-tubing annulus pressure subjects the casing to a hoop stress that exceeds 70 percent of the minimum yield strength of the casing, or if there is more than 200 psi change in the pressure between consecutive pressure readings. Amoco Production Company requests to use the 70 percent limit as the alarm for immediate notice and corrective action. By using the 70 percent yield pressure limit, the injection wells can be monitored to detect leaks and operated safely. Tubing pressure changes and temperature effects during various workover, logging, or testing operations often yield casing-tubing annulus pressure changes greatly exceeding 200 psi. These operations are necessary and occur often during prudent operations. In addition, the annular pressure is sensiti ve to injection pressures and fl uid temperature. Thermal effects and injection rate variation will be a significant controlling factor for casing pressure on water and waste disposal wells. r . . SEcn ON P WELLS WITHIN AREA 20 AAC 25.402(h) 20 AAC 25.252(h) The wells within the South Middle Ground Shoal Field, Platform Dillon are shown on Figure B. To the best of Amoco Production Company's knowledge, the wells within the area were constructed, and where applicable, abandoned to prevent the movement of fluids into freshwater sources. ('1 . . SECTION Q GAS-OIL RATIOS 20 AAC 25.240 (b) & (c)(1) If this application for an Area Injection Order is approved, then a waiver is requested for 20 AAC 25.240(b) requiring no oil well to exceed 100 percent of the original solution gas-oil ratio. The requirement for an oil well to produce at below 100 percent of the original solution gas-oil ratio will not be necessary in accordance wtih 25.240(c)(1) because the pool will have an approved additional recovery project in operation. ? ~ ~ r , , EXHIBIT 1 STATE OF ALASKA ù~P.~~~~L OF NATURAL ~SOUlCES DIVISION OF MI~ŒS AND mHE?J.-LS Alaska Oil and Gas Conservation Committ~e 3001 Porcupine Drive Anchorage, Alaska ?-i:: THE .-\PPLICÞ.TION OF Till: SHELL OIL COMP lllN ) ;~1) THE ?;'-N ';:1D.lc..~_N PEnOLEtr.1 CO:U>ORATION, ) cove~in3 t~e developme~t of a prescribed area ) or the ~'li¿dle Ground Shoal Field for an except- ) ien to Section 2051.1 of t~e Alaska Oil and Gas) Conservation ~egulations and ~equesting auth- ) orizatien to initiate, e)~an¿ and continue ) pressure maintenance or secondary recovery ) operations purusant to the aut~ority granted ) by Section 31.05.030 of the Alaska Statutes ) Conservation Order #44 July 19, 1967 IT P.PPL:"':'U:'G TIi.\7: 1. i~è S~~ll Oil CODpâny and the PEn ~nerican PetroleU8 Cor?oration submitted a petition dated June 9, 1957, requesting the referenced exceotions- and authoriza- tions. 2. Notice or the hearing ~as published 1967. úecause of a tj~ographica1 error hearing ~as republished July 8, 1967. in the in the , ! Anc~orage Daily ~e~son July 3, original pub ì ieat ion the no-tice of , - , I j p~rt.ies. ] . A ~aiver of personal service was received fro~ eac~ ot the affected . f ( .\ pujlic nearing ~as held in the City Councii Ch=~e::-s of Ò.e Z. J. Lþuss.J.c Library on July 19, 1967. Testi=ony in support of the petition ~as presented by ! Pan A~erican Petrole~~ Corporation and Shell Oil Coop any. ~~ IT FUlT~~ APPEA~I~G that reservoir data presented at the hearing is adequate t~ dete~i~e that an exce~tion to the acreage spacing requirements of Section 2061.1 of the Alaska Oil and Gas Conservation ~egulations is necessa~y roc the affected area hereinarter described. nf / " i ~ ~ CONSElVATION ORDB. :,44 Page 2 July 19, 19ó 7 Þ~D IT FUlTHLR ~~PEA1ING that the data on the reservoir performance as shown at the hearing indicates that tests to dete~ine the feasibility of pressure rnain- tena,ce or secondary recovery operations by fluid injection should be ipitiated and :iat Field lules authorizing such testing ~nd initiation of pressure mainten- ance or secondary r~covery operations and a continuation and expansion of such 0perations if proven feasible should be adopced. &~ IT F~THEl )~?S~ING that certain changes should be nade to enlarge the affected are41 and ::Jodify rules listed in Conservation :)rder ~31. Þ~D IT FURrdE~ AP?S~~ING that pool rules establishing requirements for bottom hole prèssure surveys, gas-oil ratio surveys, and niniw~ casing and cementing require- ::Jents should be adopted for the affected area. ~o~, THER~FORE, IT IS ORDE~D that the area described as follows is affected by this order: T3N-?,13~ , s. a. Section 1 : All Section 22: S£/4 Section ~ E/2 Section 23: All L: Section 11: SiJ / ~, E/2 Section 24: W/2 Section 12: S:J/4, ~¡/2 Section 25 : '~/2 Section 13: '-'/2 Section 26: All Section 14: All Section 27: E/2 T9N-:U2:.¡ , S. ~. T9N-l13:'¡, s. M. Secti:::n 19 : s/2 Section 25 : E/2 Section 30: All Section 36: E/2 Sec t ion 31. P.ll The following special rules apply to the aforementioned area: lule 1, SDaci~g patt~rn (~) Oil wells ::Jay be completed closer than 500 feet to the section lines or quarter secticn lines and Day be completed closer than 1000 feet to any well drilling to or capable of producing from the same pool, except that no oil well shall be coapleted ac a distance of less than 500 feet from a lease line where ownership c~anges. ~ .t' CONSr:RVATION ORDER :;144 Page 3 July 19, 1967 (b) No more than two oil completions shall be allowed in any governmental quarter section or goveramental lot corresponding thereto in any pool as designated in Rule 2. ~ule 2, Pool designation The vertical producing intervals shall be divided into seven (7) pools which will be correlated with the following intervals in the Pan American Petroleum Corporation ~tate 17595 ~4 well. ::-!GS Oil Pool A - 5300' to 5720' MGS Oil Pool B - 5720' to 6100' XGS Oil Pool C - 6100' to 6400' XGS 0.1 Pool D - 6400' to 6750 t 1._ MGS Oil Pool E - 6750' to 7050' XGS Oil Pool F - 7050' to 7375 ' :·fGS Oil Pool G - 7375 ' to 9215' Rule < Per::1issible cOCDina,lir.~ - , A well ~ay be cOwpleted in and produced siwultaneously from anyone or more, or frow all or the above seven pools provided that the production rro~ the pools is ade~uately segregated in the :<ell bore and ?roduced at the sur=ace so that the following re~uirements may be met: --~ (a) Production from XGS Oil Pool A, as defined in Rule 2, ~ ~ust be segregated in the SaDe well bore from production originating frc~ any other pool. (b) Production rrow ~~S Oil Pools B, C, and D, as defined in Rule 2, may be co~ingled in the s~~e well bore, but ~ust be segre- gated frem production from any ether pool. (c) Production from ~fGS Oil Pools E, F, and G, as defined in Rule 2, may be co=ingled in the same well bore, but must be segre- gated frow production from any other pool. Rule 4, Fluid iniection The injection of fluid into any of the pools described in Rule 2, for ~~e purpose of pressure maintenance or secondary recovery or or conducting injecti- vity tests, is hereby pe~itted, subject to the following require~ents: ( í ~ ~ CŒiSERVATION om:::'.. #44 Page 4 July 19. 1967 (a) Fluid injected into MGS Pool A must be segregated f~om and injected separately in the well bore from fluid injection through the szme well into any other pool. (b) Fluid to be injected into ~~S Pools B. C. and D. may be comningled in the well bo~e and injected simultaneously into all three pools. but ~st be segregated from and injected separately in the well bore from fluid injection through the same well into any other pool. !c) ?luid to be i~jected into P£S Pools E, F. and G, cay be cornningled in the well bore and injected simultaneously into all three pools. but 3Ust be segregated from and injected separately in the well bore from fluid injected through the s~e well into any other pool. (d) The same well may be used for both injection and producing purposes simultaneously provided that the requirements of Rule 3. and of Rule 4 (a), (b), and (c) above are met. and there is an adequate shut-off betveen that part of the well used for injection purposes and that part used for production purposes. Rule 5, Lease line well ---. r~e drilling of a well to be completed in the pools defined in Rule 2. at a locaticn as nearly as practic~ble upon the township line be~~een Township 3 North and lo~r.1shi? 9 North and the boundary line separating Lease ADL 17595 fro~ Lease )~L 13754 is hereby ?e~itted. upon a showing being made to the Co~ittee that an appropriate agree~ent therefor has been entered into by all affected parties. including the State of Alaska as lessor. Said well may be completed and produced as an oil well but shall not be considered as one of the two veIls attributable to a quarter section for the purposes of Rule 1 as to either Lease ADL 17595 or Lease ADL 18754. Said well cay at any ti~e thereafter be converted to injection purposes. The Co~ittee shall be notified of the effective date of the change. Rule 6, Administrative approval of changes in pressure maintenance or secondary recovery ooerations rne Co~ittee cay upon a showing that the operators of each of the leases. as the representatives of all affected parties. concur in the request therefor and that appropriate and adequate casing. cementing, and testing has been, or will be. carried out, authorize any of the following operations as an adcinistra- tive matter and without notice or hearing: ~ ~ OONSE~VATION O?~ER #44 Page 5 July 19. 1967 (a) The conversion to injection purposes or any well initially completed either as a producer of oil or as a dry hole. (b) The drilling for injectioD. purposes of a well or wells' at any location. (c) The conversion from injection purposes to producing stat~s of any well or wells. (d) The drilling of additional wells. i.e. wells not otherwise a~thorized by these Field Rules, for producing purposes at any location. (e) The co~ingling in the well bore cf fluid produced by a well fro~ ~ay pool defined by ~ule 2. with fluid produced by said well from any other pool or pools defined by Rule 2. (f) The comoingling in the well bore of fluid injected through a well into any pool as defined by Rule 2 with fluid injected through said well into any otner pool or pools as defined by Rule 2. lule 7, Casin£ and cementing require8e~t$ Surface c¿sing must be set and ceDe~ted to a depth or at least lóOO feet. Sufficient ce~ent ~ust be used to ci~culate to the sur:ace. The p~oduction string must be ce8ented with a sufficient vol~e of cement to extend at least 500 feet above the shoe or a volume to cover the uppercost pro- due in; zone encountered in the well. whichever is greater. lule 3, Bcttomhole pressure surveys An annual key well bottom hole pressure survey shall be oäde during the Qonths of January and February ~Jith the results to be reported to the Co~ittee by the end of Xarch each year. The operators in the field, with approval oE the Co~ittee. will dete~ine the datuc; the wells to be included, the method to be used and the t}~e of info~ation to be secured. Bottom hole pressures obtained by a static build-up pressure survey. a 24 hour shut-ia instantaneous test o~ a Dultiple flow rate test will be acceptable for this pu~ose. Survey results will be reported on Fo~ P-12 or other appropriate means agreed to by the operators and the Coomittee. " . ~ ~ Cm¡SERVATION mDER. 1144 Page 6 July 19, 1967 Rule 9, Gas-oil ratio tests A gas-oil ratio test of 24 hours duration shall be made on each producing well annually. The test will be made during the months of January and February and the results will be reported on Form P-9 by the end of March of each year. The requirements of this rule will be waived if monthly reported oil and gas production is based on a gas-oil ratio test made at least every SL~ ~onths by the operator. '" IT IS FURTI1ER OlD~R.ED that Conservation Orders 1126 and #31 are superceded by Coaservation Order #44. Lìis Order is made pursuant to Section 2061.3 of the Alaska Oil and Gas Conservation Regulations and the rules affecting well spacing shall continue in force for a period of not more than eighteen (18) moaths pro- vided, however, that wells which have been drilled and completed and are being produced in comp~iance with the provisions of this Order, or any other Order of the CoQffiittee, ~ay be produced in compliaace with the terms or said Order not- withstandir.g the fact that such Order may have expired or have been terminated, or that there may be ?ending a request that said Order be modified or terwinated, until such ti~e as the Co~ittee shall, after notice and hearing, enter an Order establishing different rules, requirecents, or provisions. The Co~ittee on its O\m 2Otion, or at the request of any interested party, cay at any ti::1e during the teDpor2ry period set this matter for further hearing for the purpose of deter- mi:Üng ,.¡hether the present Order should be æJended or modified. T~e Co~ittee ~ill, in the absence o¡ a request of an interested p~rty for a hearing at an e;:¡rlier date, set tiÜs matter for hearing Eor a d;:¡te ,,,hieh s hall be not later than 30 d;:¡ys prior to the date or the expiration of this Order, for the pur?ose of deter::1ining the proper spacing and field rules which should then be app licable to this field. ( (m)Î~\ \ (.,,-, ~,,,..> ~ ft CONSE~VATION OlOE? #44 Page 7 July 19, 1967 DONE at Anc~orage and Juneau, Alaska, and dated July 19, 1967. d-./S ¡Ú{~·t. ThoDas R. Marshall, Jr., Executive Secretary Alaska Oil and Gas Conservation ComDittee " Concurrence: Chairoaù. Conservation ComDittee /:) .Þ ." / 1 /;~~ ..<L --;;U.:-. dt.~-¿¿CA...-C-9~ ;)ale ¡Iallingto:;., ~·le:::Ø-er ~laska Oil and Gas Conservation CoWDittee KIf(t(::f{~ Alaska Oil and Gas Conservation Co~ittee ~ , STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF MINES AND MINERALS Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska Re: THE APPLICATION OF THE PAN AMERICAN ) PETROLEUM CORPORATION, for an extension of ) the Field Rules established by Conservation ) Order 144 to include all of the Middle Ground ) Shoal Field which is in the South Middle Ground ) Shoal Unit Area. ) Conservation Order g 53 September 7, 1967 IT APPEARING THAT: 1. The Pan American Petroleum Corporation submitted a request dated August 14, 1967 for an order extending the Middle Ground Shoal Field Rules established by Conservation Order #44 to include other areas of the Middle Ground Shoal Field, hereinafter described. 2. The area requested for inclusion is underlain by the same geologic feature which is productive of oil and gas within the area now subject to Conservation Order g44 and one well has been drilled to and completed in an oil pool which appears to be MGS Oil Pool G, as defined in Conservation Order #44. 3. The area requested for inclusion has similar structural, stratigraphic, and reservoir relationships and indicates that at least one accumulation of oil is common to the area defined in Conservation Order #44. 4. Notice of hearing on the petition was published in the Anchorage Daily News on August 22, 1967, pursuant to Section 2012 of the Alaska Oil and Gas Conserva- tion Regulations, but no protest for hearing was received. AND IT FURTHER APPEARING that the hereinafter described area should be included in the general area to be covered by most of the rules set forth in Conservation Order #44. ~ CONSERVATION ORDER i/53 Page 2 September 7, 1967 , NOW, THEREFORE, IT IS ORDERED that the area described as follows is affected by this order: Township 7 North, Range 13 West, S.M. Section 1: NW~ ':. Section 2: All Section 3: All Section 10: W~ and SE~ Section 11: NW~ Township 8 North, Range 13 West, S.M. Section 27: SW ~ Section 34: All Section 35: All Section 36: W~ AND IT IS FURTHER ORDERED that the special rules and directives set forth in Conservation Order~44, with the exception of special rule 5, shall also apply to the above described area and the rules affecting well spacing shall continue in force for a period of not more than eighteen (18) months beginning July 19, 1967. DONE at Anchorage and Juneau, Alaska, and dated September 7, 1967. ,0 . f !!;I /JJ" I UlJ-ß,¡, i/I ~(J. -It. Thomas R. Marshall, Jr:, Executive Secretary Alaska Oil and Gas Conservation Cammittee ~'. ("' Concurrence: J es A. Williams, Chairman Al skj. Jfl and Gas Conservation ~-t~_ ~/,~~.~ Dale Wallington, .MembeV Alaska Oil and Gas Co~ervation Coumittee Committee fi( //../ ~/ Í, /," J~F Z, </ ......, /...-:-<-- L~;:': _ / __ Karl L. VonderAbe J Member Al~~k~ nil ~~n ~~C r~~~n~.~~~__ ~---:~~-- ,. " STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF MINES AND MINERALS Alaska Oil and Gas Conservation Committee Re: THE APPLICATION OF THE PAN AMERICAN ) PETROLEUM CORPORATION, for a redescription ) of the area affected by Conservation Order #53 ) Conservation Order # 54 October 12, 1967 IT APPEARING THAT: 1. .The Pan American Petroleum Corporation submitted a request dated September 2~ 1967 for a correction of the typographical error in the description of the affected area in Conservation Order #53. 2. An error in the description of the affected area in Conservation Order #53 does exist. 3. Notice of hearing on the request was published in the Anchorage Daily News on September 29, 1967, pursuant to Section 2012 of the Alaska Oil and Gas Conservation Regulations, but no protest for hearing was received. AND IT FURTHER APPEARING that the correct description of the area affected by Conservation Order #53 is as follows: Township 7 North. Range 13 West. SM. Section 1: m.¡~ Section 2: All Section 3: All Section 10: N~ and SE~ Section 11: NW~ Township 8 North. Range 13 West. SM. Section 27: SW~ Section 34: All Section 35: All Section 36: W~ NOt.¡, THEREFORE, IT IS ORDERED that the area described above is affected by the rules and directives stated in Conservation Order #53. " ~ " t _ .. CONSERVATION ORDER #54 Page 2 October 12, 1967 DONE at Anchorage and Juneau, Alaska, and dated October 12, 1967. tÅ,. I 11¡{~dl j Thomas R. Marshall, Jr., Executive Secretary Alaska Oil and Gas Conservation Committee Concurrence: . s A. Williams, Chairman A a~k7Ja. Oil an~ Ga.s Conservation / ~--,// 7 +--. 1j~'¿1/¿ //¿¿ Ctu--i..-1{/7/\-/ Dale Wallington, M~~er Alaska Oil and Gas Conservation Committee Committee /7 . ~ - L;"7/} . i tI//. !l:,--^-- /Ä jz, c-~~L L <- Karf L. VonderAhe, Member Alaska Oil and Gas Conservation Committee 1 . . . Notice of Public Hearing J I (/ 7 +;;'ìì_ -- STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of AMOCO PRODUCTION COMPANY for Area In- jection Orders for those portions of the Middle Ground Shoal Field developed by their Baker and Dillion platforms in the Cook Inlet. The Alaska Oil and Gas Conservation Commission has been requested, by letter dated July 15, 1986, to issue orders for area injection to provide authorization for utilizing existing service wells permitted for injection by the U.S. Environmental Protection Agency and subsequent service wells permitted in accordance with 20 AAC 25.005 or 20 AAC 25.280 to inject fluids underground for purposes of enhancing oil recovery from the Middle Ground Shoal Pools A, B, C, D, E, F and G as defined by Conservation Orders No. 44, 53 and 54 and for the disposal of non-hazardous oil field fluids into shallower tertiary strata. ke~ Commissioner Alaska Oil and Gas Conservation Commission Published July 31, 1986 'ì ~. ~) (i STATE OF ALASKA ADVERTISING ORDER . ". F R o M Anchorage Daily News P. O. Box 149001 Anchorage, Alaska 99514-9001 T o p U B L I S H E R Alaska Oil & Gas Conservation Ccmnission 3001 Porcupine Drive Anchorage, Alaska 99501 . AGENCY CONTACT Ga1yn Evans PHONE ~o~ 279-1433 DATES ADVERTISEMENT REQUIRED: ADVERTISING ORDER NO. AO- 08-5566 DATE OF A.a. July 29, 1986 July 31, 1986 SPECIAL INSTRUCTIONS: ):AFFIDAVIT OF PUBLICATION UNITED STATES OF AMERICA STATE OF~ ~~ ss DIVISION. BEFORE ME, THE UNDERSIGNED, A NOTARY PUBLIC THIS DAY PERSONALLY APPEARED#~t/!...U~ WHO, BEING FIRST DULY SWORN, ACCORDING TO LAW, SAYS THAT ~ ß '~J.. HE/SHE IS THE OF .Ø\ I .- - PUBLISHED AT ~ IN S(,D DIVISION , ~ AND STATE OF ø~~ --AND THAT THE ADVERTISEMENT, OF WHICH THE ANNEXED IS A TRUE COPY, WAS PUBLISHED IN SAID PUBLICATION ON THE 3!4- DAY OF ~ ,¿, AND THEREAFTER FOR~ CONSECUTIVE DAYS, THE LAST PUBLICATION APPEARING ON THE ~AY OF ~' 19.f&., AND THAT THE RATE CHARGED THEREON IS NOT IN EXCESS OF THE RATE . cz.o PRIVATE INDIVIDUA~ ~~~II1'IC~ ~ , , SUBSCRIBED AND SWORN TO BEFORE ME THIS 11- DAY OF ~'Sl..!t~~ 19çtp l"A'CtLQ JlJ..;fl)L.D-.eQ~_ ;'4· C NOTARY PUBLIC FOR STATE OF . ' : "n1/h'ssl,," r£xr>h... MY COMMISSION EXPIRES "uvem'::er í8, Ì):L 02-901 (Rev. 6-85) PUBLISHER REMINDER- INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COpy OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. r NotiC¡¡ Of Public ""iring . ~~, STATE OF ÁLASKA . . Alaska 011 and Ga, ,} .Conll4ll'Vatlo." Comml~lon Re: The application Of AMOCO PRODUCTION COMPANY for an Area In«tlon. Order' for "'- þCII'tlons of the Middle ,Ground Shoal Field developed , by their Baker and Dillion plat, form,'I.n the Cook. !nlet,,:,: . The Alaska 011 and Gas Conser- vation Commission ha, been requested. by letter dated July . 15. 1986. to Issue an order for ern InleCtlon to proIIlde au· thorlzatlon for utilizing 8XlStlllli' tarvlce well, permlned for lit' «t10ll by the U.S. Environ- mental' Protection Agency and IUbseauent II4II'Vlce well, per' . mltteci In eccontance with 20 MC 2$.005 or 20 MC 25.210 to j Inect fluids underground for, ~ of enhancing Ofl' re- CIMI'Y fnIm the Middle Grouncl SIIoeI ..... A. B. C. D. E. F IncI G . defined by Conll4ll'Va~ tIon 0rdIn No. .u. 53· tncI ~ and for the. dlsposel. Of .-. hazardOUS ,~fleld flulds~tnto " " ~ shell_htrtlery stratll; ',"" i"'''' Parties who wish to protest the grantIng of the referenced reo quest are allowd 15 days from the date Of thIs publication In which, to file a wrlltelì request for a hearing. The place Of filing Is the Alaska 011 and Ga, Conservation CommISSIon. 3001 Porcupine Drive.' Anchorage, Alaska 99501. If . proteit anti. request for heerllltl IS tlmety filed. a ....rln. on the maner will be llelcf afthe allov. ael- cfress at "GO AM on Alllust 30, 1"" In conformnace with 20 MC 25.540. If a hearln. I' to be held. Interested pertles may confirm thl' by calling the Commission's office., (907) 279· 1433. efter AuOUSt IS, 1986. If no ,ue" protest IS tlmety ..fllee!, tile Commission will consider tile Issuance of, the order without . ....1'IIIt/.. ;' c,; <,', ,,~ I)" ì III/Lonnie C. Smith '/1 ,: ,.,' . ,ie·,.." ; Commissioner . " Alaska 011 and Ges eanserv. tlon Commission, '" . .,.:, A Pub: JUly 31. 986 '. . ";. ;:: ; J AO*5566 .) ,"',' ,I, J', \..."'t , RECEIVED AUG 1 3 1986 Alaska Oil & Gas Cons. Commission Anchorage , It I- ~T~ AMOCO ~I~ Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 W. G. Smith District Manager July 15, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: FEW-170-986.511 South Middle Ground Shoal Field Area Injection Order Application Attached is the South Middle Ground Shoal Field, Platform Dillon, area injection order application. Amoco Production Company as operator of the South Middle Ground Shoal Field, Platform Dillon, requests that an area injection order be issued for existing and future injection wells in the field. The injection wells will utilize Tertiary age formations and will be used for fluid disposal or enhanced recovery. This application is submitted in accordance with the regulations of the Alaska Administrative Code, Title 20 - Chapter 25, revised April 2, 1986. The transfer of authority from the EPA to the Commission affects both existing and future injection wells. Existing wells are authorized by prior permits and it is Amoco's understanding that those authorizations remain in place until an area injection order is issued. Attached are five (5) copies of the application for your use. Please con- tact Mr. Fred White (263-2206) or Mr. Jeff Blagg (263-2207) if you have questions or require additional information. Sincerely, io-~ RECEIVED JUL 2 4 1986 Alaska Oil & Gas Cons. commission Anchoraae W. G. Smith District Manager JCB/dds Attachments ~<) 'e e August 29, 1986 CO COMM COt'J~~'" "-(' ENG Amoco Production Compan -,t~" .:\ C"l c·,(.'"' Post Office Box 100779 '-,:. ,:h~_ Anchorage, Alaska 99510 SR EN.;¡ 907-272-8471ENG SR GEOL SR GEOL I E·f;n.fÄsSTI ENGÀSST ¡- STAT'rEcAl STÄT-tËèH\ FILE: ¡Hð #~'»f8 W. G. Smith District Manager Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 file: FEW-220-986.511 Supplemental Data on Waste Disposal Horizons Area Injection Order Applications Middle Ground Shoal and Granite Point Fields In reference to our applications for Area Injection Orders, Platforms Baker and Dillon at the Middle Ground Shoal Field, and Platforms Anna and Bruce at, the Granite Point Field, the attached supplemental data concern- ing horizons for waste disposal is submitted for your consideration. Please contact Mr. Jeff Blagg or Mr. Fred White at 562-2147 if you have questions or require additional information. '-~}.,i'[[~ _~",~M;.~.;. Sincerely, ø~ ~;ff~': W. G. Smith District Manager JCB/dds Attachments 108/jcb1 'j ,., ,f' RECE\VED SEP 0 41986 comm\sslon AI k8 Oil & Gas Cons. as Anchorage -~....:~!' ~"",..-;"~.,,.~.,- II ....... .":)~t· ,,~\1' .¡ ·i.~·::·--~· '<0', :~_ o C,' 'J I ,. . e ,J. AìO~,~ WASTE DISPOSAL HORIZON INFORMATION PLATFORMS ANNA AND BRUCE GRANITE POINT FIELD The horizons affected by injection for waste disposal are defined by the following depths in the Mobil-Union Granite Point No.1 well: Kenai Group Tyonek "A" Sand Kenai Group Tyonek "B" Sand 5,941 - 6,4321 6,432 - 7,7141 True Vertical Depth 5,920 - 6,4111 6,411-7,6931 Horizons Name Measured Depth The Tyonek "A" and "B" sands are an argillaceous channel sandstone and conglomerate interbedded with siltstones, shales, and coals. The sandstone and conglomerate is predominately quartz and chert with inter- spersed igneous and metamorphic rock grains. The confining zones between, above and below the disposal horizons are a series of tight, impermeable siltstones and shales, varying in thickness from 50 to 200 feet. RECE\V£D SEPO 4 t9Ø6 eomm\Ss\on 01 & Gas Cons. Alaska I AnchOrage I~ "T~ AMOCO ~I'" e e Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 W. G. Smith District Manager July 15, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: FEW-170-986.511 South Middle Ground Shoal Field Area Injection Order Application Attached is the South Middle Ground Shoal Field, Platform Dillon, area injection order application. Amoco Production Company as operator of the South Middle Ground Shoal Field, Platform Dillon, requests that an area injection order be issued for existing and future injection wells in the field. The injection wells will utilize Tertiary age formations and will be used for fluid disposal or enhanced recovery. This application is submitted in accordance with the regulations of the Alaska Administrative Code, Title 20 - Chapter 25, revised April 2, 1986. The transfer of authority from the EPA to the Commission affects both existing and future injection wells. Existing wells are authorized by prior permits and it is Amoco's understanding that those authorizations remain in place until an area injection order is issued. Attached are five (5) copies of the application for your use. Please con- tact Mr. Fred White (263-2206) or Mr. Jeff Blagg (263-2207) if you have questions or require additional information. Sincerely, 10-£ RECEIVED JUL 24 1986 Alaska Oil & Gas Cons. Commission Anchorage W. G. Smith District Manager JCB/dds Attachments . -"'\ (> 1.lt, j , e It SECT! ON A AREA INJECTION ORDER 20 AAC 25.460 Amoco Production Company, as operator of the South Middle Ground Shoal Field, Platform Dillon, Lease ADL-18746, requests issuance of an Area Injection Order to authorize the use of service wells to inject fluids underground for purposes of enhancing oil recovery, and for disposal of non-hazardous waste fluids generated during normal drilling, workover, and production operations. The Area Injection Order will encompass all lands within the boundary of the South Middle Ground Shoal Field (SNGS), Platform Dillon, Lease ADL-18746, as defined by Conservation Order No. No.ls 44, 53, and 54. These Conservation Orders are attached as Exhibit 1. The lease boundary and area operated by Amoco Production Company is shown in Figure A. RECE\'JED JUL 2 4 1986 commission . & Gas Cons. f>..\as\<.a 011 Ancheta!)6 () 0 TABLE 4 PLATFORM DILLON Tubing/Casing Pressure Test Date Requ ired Existing Packer Annulus Operating Complete Setting Test We 11 No. Status Run Depth Pressure Remarks 8RD Injecting 09/85 9,750 MD 2400 8,997 TVD 9RD2 Injecting 06/85 10 ,200 MD 2500 9,464 TVD 11 Injecting 01/81 9,320 MD 2400 9,002 TVD 12 Injecting 06/81 10 ,051 MD 2300 8,627 TVD .~ ~"- ~ ~ . "'.~ ~ ," ,,'" ~ ..... ~) C_', ,'.~ .... . ."" CJ~' < V "'v ð.- ~'" .f...-.. ..~ _~'? I~-> ,rJ;;~ ~.¡ '-' '\:)'~ ~ -H .~ . e . e flIt) M,~. ~'f'8 WASTE DISPOSAL HORIZON INFORMATION PLATFORMS BAKER AND DILLON MIDDLE GROUND SHOAL FIELD The horizons affected by injection for waste disposal are defined by the following depths in the Pan American Corporation State 17595 Well No.4: Hori zon Name Measured Depth 2,620 - 3,090' 4,330 - 4,955' True Vertical Depth 2,534 - 3,004' 4,244 - 4,869' Kenai Group Tyonek "A" Sand . Kenai Group Tyonek "c" Sand The Tyonek "A" sand is an argillaceous channel sandstone and conglomerate interbedded with siltstones, shales, and coals. The sandstone and con- glomerate is predominately quartz and chert with interspersed igneous and metamorphic rock grains. The Tyonek "c" sand is composed of quartzitic, matrix supported conglomeratic sandstones, interbedded with siltstones, shales, and coals. The beds were deposited by braided streams migrating across the width of their flood plains. The confining zones between, above and below the disposal horizons are a series of tight, impermeable siltstones and shales, varying in thickness from 50 to 200 feet. RECE\\JED SEPoz.1986 - C mm\ss\on on & Gas Cons. 0 Alaska AnchOrage .1 J ,~ .-.T.. AMOCO ~I~ . . Amoco Production Company Post Office Box 100779 Anchorage. Alaska 99510 907-272-8471 w. G. Smith District Manager July 15, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: FEW-170-986.511 South Middle Ground Shoal Field Area Injection Order Application Attached is the South Middle Ground Shoal Field, Platform Dillon, area injection order application. Amoco Production Company as operator of the South Middle Ground Shoal Field, Platform Dillon, requests that an area injection order be issued for existing and future injection wells in the field. The injection wells will utilize Tertiary age formations and will be used for fluid disposal or ~nhanced recovery. This application is submitted in accordance with the regulations of the Alaska Administrative Code, Title 20 - Chapter 25, revised April 2, 1986. 1-( 0 t£I The transfer of authority from the EPA to the Commission affects both existing and future injection wells. Existing wells are authorized by prior permits and it is Amoco's understanding that those authorizations remain in place until an area injection order is issued. Attached are five (5) copies of the application for your use. Please con- tact Mr. Fred White (263-2206) or Mr. Jeff Blagg (263-2207) if you have questions or require additional information. Sincerely, Ø-k RECEIVED JUL 2 it 1986 Alaska Oil & Gas Cons. commission Anchorage W. G. Smi th District Manager JCB/dds Attachments ,. ~\ SECTION A AREA INJECTION ORDER 20 AAC 25.460 Amoco Production Company, as operator of the South Middle Ground Shoal Field, Platform Dillon, Lease ADL-18746, requests issuance of an Area Injection Order to authorize the use of service wells to inject fluids underground for purposes of enhancing oil recovery, and for disposal of non-hazardous waste fluids generated during normal drilling, workover, and production operations. The Area Injection Order will encompass all lands within the boundary of the South Middle Ground Shoal Field (S~1GS), Platform Dillon, Lease ADL-18746, as defined by Conservation Order No. No.ls 44,53, and 54. These Conservation Orders are attached as Exhibit 1. The lease boundary and area operated by Amoco Production Company is shown in Figure A. RECE\VED jUL 24 1986 cornmizsìO[l . ka Oil &. Gas Coos. ,l\\as AnchOf3!]e + + TI " ~ 24 g, ¿,,:) N1 ~- + I /~b 25 !i) + + 20 + + lCJ 30 + + I + + 35 36 I 31 32- -ÎDL 17SQS RI3W RI2.w - - - ~-----¡ 7, 2- 6 ....) + + + + 10 " IZ. 7 ADl /8754 + + + + /5 14 13 T 18 B + + + N + ",1') 2.3 2.4 /9 t...._ ~... + + + + [III II L: 7 26 25 30 - - RECEIVED - - ADL 18756 - - - - - - - ::1111111~1111111111111111~IJllllllL + J U L 2 4 1986 -- - - - - ADL 16746 :: - \ - - ~ 31 Alaska Oil & Gas Cons, Commission - - 31./ 35 36 - - - Anchorage - - - - - ~- - - - - - - - - - - - - --- - - --- - - - - - - - - - - - - - - 3 2 IUJ II iii I 6 - - - - - - ~ - - - - - - + - + - --- illUlU e- - - - - - - SOUTH MIDDLE GROUND SHOAL FIELD - - - - I - ~ rrfmm! 0 wum-¡ / IZ '7 I - - - - - - - - - - + + mlllll~ + T 7 /5 /If 13 N + + + Amoco Production Company FIGURE A e e SECTION B PLAT 20 AAC 25.402 (c) (1) 20 AAC 25.252 (c) (1) Figure B is a plat showing the location of all wells that penetrate the uppermost injection zone within the SMGS Lease ADL-18746 boundary. ,w.,··~·· . ....... ....... - -1'---- I I 3Lf T\ 81 ---$-1 ~\ \ \ \ 3 I I 121 AI \ I ----~ - ~ \ I 10 e 2. -.- 14 . -,- 13 . 3 . 2RD . I I I I LN- Â._ d_.____ ___.___ +_ I I I I I I I I I- I I' I I I '1 I SOUTH MIDDLE GROUND SHOAL FIELD FIGURE B I -----.- --- - - .--- - -- - + I e 8 8RD -f- A C .~ C\ RD Å 4- . 35 II. 6 . R 13'v1 -- ---- - -- 7 Â 5 . 2 :.> 'f/I; _~'-¡t~ ~O~Ö) ~,~ Amoco Produètion Company II e e SECTION C OPERATORS/SURFACE OWNERS 20 AAC 25.402 (c)(2) 20 AAC 25.252 (c)(2) The surface owners and operators within the area of this Area Injection Order and extending 1/4 mile beyond the boundary (excluding Amoco Produc- tion Company) are: * State of Alaska Department of Natural Resources 3601 C Street Anchorage, Alaska 99503 Shell Western E and P, Inc. 601 West Fifth Avenue Suite 810 Anchorage, Alaska 99501 * e See attached affidavit SECTION 0 AFFIDAVIT 20 AAC 25.402 (c)(3) 20 AAC 25.252 (c)(3) e tl':. e e AFFIDAVIT STATE OF ALASKA THIRD JUDICIAL DISTRICT Jeffrey C. Blagg, being first duly sworn on oath, deposes and says: That I am an employee of Amoco Production Company. That on the n2( day of July, 1986, I caused to be mailed a true and correct copy of this app1ica- tion to the following operators and surface owners listed in Section C: Mr. Jim Eason, Acting Director Division of Oil and Gas State of Alaska Department of Natural Resources P.O. Box 7034 Anchorage, Alaska 99510-0734 Mr. M. L. Woodson Shell Western E and P, Inc. 601 West Fifth Avenue Suite 810 Anchorage, Alaska 99501 ~)f I. , e e by placing a said copy in the United States Mail with postage prepaid and certified at Anchorage, Alaska. SUBSCRIBED AND SWORN to before me this ~\ ~ day of July, 1986. .ffi(.~~c and for Alaska ,viy CO:Clm;ssion Expires; My commission expires May 2, 19S'____ · e SECTION E DESCRIPTION OF OPERATION 20 AAC 25.402(c)(4) Current and proposed injection operations at SMGS Lease ADL-18746 are divided into two broad categories: enhanced recovery and fluid disposal. Enhanced recovery injection wells are used for the introduction of dis- placing fluids into the reservoir to increase the ultimate recovery of oil. Currently, water injection is the only method of enhanced recovery in use at SMGS Lease 18746. The injection system utilizes Cook Inlet sea water passed through a network of filters, piping, injection pumps, and manifolding. Future injections may incorporate the injection of produced formation water or polymers. Existing water injection wells and future injection wells will continue to be designed, constructed, operated, and monitored to ensure the injection fluid is entering the oil reservoir. Enhanced oil recovery methods are/will be confined to Tertiary age for- mations. Presently, there are no disposal wells used for the disposal of produced water or other non-hazardous waste fluids generated during normal drill- ing, workover, or production operations. Future disposal \'ælls for injecting these waste products will be designed, constructed, operated, and monitored to ensure the injected fluid is confined to the injection zone. Waste disposal will be confined to Tertiary age formations. , : .~ e ,e SECTION F POOL INFORMATION 20 AAC 25.402 (c)(5) The South pools affected by injection for enhanced recovery and waste disposal are defined by Rule 2 of Conservation Order No. 44 as the following measured depth intervals in the Pan American Corporation State 17595 No.4 Well: MGS Oil Pool A - 5300' to 5720' MGS Oil Pool B - 5720' to 6100' MGS Oil Pool C - 6100' to 6400' MGS Oi 1 Pool o - 6400' to 6750' MGS Oil Pool E - 6750' to 7050' MGS Oi 1 Pool F - 7050' to 7375' MGS Oil Pool G - 7375' to 9215' r; {'; · e SECTION G GEOLOGIC INFORMATION 20 AAC 25.402 (c)(6) 20 AAC 25.252(c)(4) The South Middle Ground Shoal anticline is a long, extremely narrow anticlinal feature which strikes north 10° east on the northern portion. The field is located at the crest of the anticline. The east flank dips from 33°E near the crest to 69°E at the extreme east flank in 17595 No.9. The west flank dips between 55-800W as implied by the 17595 No.8. Depositional patterns in South Middle Ground Shoal indicate that the anticline did not exist during Oligocene to Miocene deposition. This is illustrated by the lack of thin or bald spots along the crest of the anticline in the depositional patterns. Although sand thickness within each Tyonek zone varies a great deal, pore thicknesses are very similar within each zone. Sands are generally thicker to the north and east but the best reservoir tends to be east and southeast. The Tyonek C and D sand members include units designated by the State of Alaska as Middle Ground Shoal (MGS) A through F as shown on Figure G. The A sand is an alluvial sandstone, coal, and flood-plain shale. The BCD is a fill channel deposit. The E and F are estuarine flood plain siltstones, shales and coals. The Miocene Tyonek C sands are composed of quartzitic, matrix supported conglomeratic sandstones, interbedded with siltstones, shales and coals. These beds were deposited by braided streams, migrating across the width of their flood plains. The E and F zones represent a transgressive phase with siltier sands. The best quality reservoir occurs to the northeast and southwest in the F zone. The best reservoir was deposited to the east and southeast during A through E time. Sands are thicker to the northeast only during the depo- sition of C and A sands. 'The A and BCD interval represents a regressive braided stream environment. The best quality sand was deposited on strike over the eastern flank of the field. The 01 igocene Hemlock conglomerate is the main reservior of the South Middle Ground Shoal Field. This alluvial conglomerate is composed of clast supported conglomerate interbedded with siltstone, sandstone and clays. This conglomerate was deposited by braided stream channels of low to moderate gradient flowing from the north and west. The Hemlock is composed of subrounded moderately sorted quartz, black chert pebbles and i - 4111Þ~~ . metamorphic rock fragments. This unit was deposted uncomformably over the West Foreland. The Hemlock and the overlying Tyonek section pinchout to the east on the Kenai Peninsula. The Hemlock G sands and conglomerates were deposited by braided streams shifting across their flood plain. These conglomerates have a good matrix porosity four to 15 percent and a permeability of only 2.1 md is needed for production. Extensive deposition occurred during G-3, G-4 and G-5 time. Depositional strike was north-south. During G-5 time highest sand deposition occurred along what is now the crest of the anticline. Deposition shifted north and eastward in G-4 time and the northern deposition shifted westward in G-3 time. These sands are very well developed to the north, south, and southeast of Platform Baker. The South Middle Ground Shoal area was flooded at the end of G-3 time and a low energy environment existed north of the present location of the platform. The G-2 sand tends to be a tighter sand with average porosity only four to eight percent. The G-l represents a regressive environment of braided stream deposition. Though not as thick as the G-3, G-4 or G-5, this sand is very porous especially north, east and southeast of Baker platform. The EFG sand has an average net pay thickness of 330 feet, porosity of 11 percent, and permeability of 5.4 md. The confining zones between and above producing units are a series of tight, impermeable siltstones and shales, varying in thickness from 50 to 200 feet. . i. FIGURE G tie. ~TIÄ. '. ~o "LV COOK INLET TERTIARY NOMENCLATURE Hun AGE ~IHUl PUT. ROCK UNITS SUlTE5 PLEISTO- CENE Glacial cover . Her... , . .I.d. PLJOCENE Bishop Creek mb r. H n er· Sterling Fm. s tea, Cook I n let sand mbr. ~.6 e:: hie,', Beluga Fm. 5 W es t For x m b r. ? ~ . ~ Chuitna m b r. '6 235 ::;:) Q 5-T A TE ~ 0:: t'A " san d m b r. M IOCEN E A233 I:.:) PRODUCING .... - NO M ENCLATU.R e . c=: % "BIt sand m b r. MIDDLE GROU~ ~ Tyonek Fm. ::x::: ~ SHOAL "C II sa n d m b r. "l" C::. "8" "C" "0' , sand m b r. -"D" I "f" .6 3 13 "f" ~'v bi4 01. "û" v'v ~O GHU' H em lock Conglomerate ð. V 0 333 37 4 .6. West Foreland Fm, ~ Tsadaka m br. I EOCENE I : Wishbone Fm·. PALEO· - CENE Chickaloon Fm. QHIeI UPPER CRET- Matanuska Fm. ACEOUS .' U P.PE R Naknek Fm. JURASSIC fru FI H·l' WM CONNELLY Aþ¡:lIL.197i' '_~'.'4~·..¡1___~"~4-r~;''' .~..... '"~~,,,,--,o/II_ ........' . . .. . SECTION H WELL LOGS 20 AAC 25.402 (c)(7) 20 AAC 25.252 (c)(5) All open hole logs from SMGS Lease ADL-18746 are sent to the commission as the logs are completed. f · e SEcn ON I CASING INFORMATION 20 AAC 25.402(c)(8) 20 AAC 25.252(c)(6) Typical SMGS Lease ADL-18746 injection wells are cased as shown in Figure 1. All newly completed injection wells will be cased, cemented, and tested in accordance with 20 MC 25.252. Casing design will be submitted for approval as required under 20 AAC 25.005 (Form 10-401) on the drilling permit application. In wells converted to injection, the casing will be retested in accordance with 20 AAC 25.412(c), and the well will be completed in accordance with 20 AAC 25.412(d). e " 3!..z. TußIMe,.. ~( PAc..KER. T~TE.D To 1../000 PSI FIGURE I e WELLHEAD SEA LEVEL MVD LINE // I LJO PILE @ ZOO 20// C.ONDUCTOR @ bOO/ 133/8 '/ SUR-FAG"- c..f\.<::.IN& @ 2-000" C ~'/ INH/ZME'ù\I\TE. CASING @ ToP 01" H£MLOC-k "<7-- 7" UNE.f\ @ BA~f" OF HE./II\i..o(..l<' "C;/' j' . lj í'i ;1 e , t e' SECTION J INJECTION FLUID COMPOSITION INJECTION RATE AND PRESSURE 20 AAC 25.402 (c)(9) & (10) 20 AAC 25.252(c)(7) & (8) Enhanced Recovery Fluids The type of fluid injected into enhance recovery injection wells is fil- tered, treated Cook Inlet sea water. Water treatment additives include biocide, corrosion inhibitors, scale inhibitors, and oxygen scavengers. The maximum expected injection rate on a field wide basis is 15 MBWPD, and on a per well basis is 6 MBWPD. Water sensitivity tests on core samples showed no significant problems with formation plugging or clay swelling caused by injecting Cook Inlet sea water. The maximum wellhead injection pressure for enhanced recovery injection wells at SMGS Lease ADL-18746 is 4000 psig. This pressure is the maximum discharge pressure of the injection equipment. The average injection pressure is estimated to be 3800 psig. Fluid Disposal The injection fluid for disposal is expected to be predominantly drilling, workover, and production related waste fluids. The injection stream could include drilling mud, reserve pit water, contaminated crude, diesel gel, glycol, domestic waste water and workover fluids. There are presently no waste disposal wells on SMGS Lease 18746. The maximum expected injection rate on a per well basis is 6000 BPD. The maximum expected wellhead pressure for fluid disposal wells is 4000 psig. The average injection pressure will be determined at such time that a well is converted to waste disposal. e e SECTION K FRACTURE INFORMATION 20 AAC 25.402(c)(11) 20 AAC 25.252(c)(9) The proposed maximum injection pressure for the enhanced recovery and fluid disposal wells will not initiate fractures in the confining strata which might enable the injection or formation fluid to enter freshwater strata. Enhanced Recovery The Hemlock State "G" Conglomerate has a fracture gradient of 0.9 to 1.1 psi/ft. A fracture gradient of 0.9 psi/ft corresponds to a bottom hole injection fracture pressure of 8280 psig. The surface injection pressure is estimated to average 3800 psig with a maximum projected pressure of 4000 psig. Since startup of waterflooding at SMGS Lease ADL-18746, injection surveillance data has been collected. Such data has included injection profiles, temperature surveys, injectivity index monitoring, pressure fall off, and step rate tests. This information has verified that water injections have not extended into freshwater zones. Fluid Disposal Injection zones for fluid disposal may exhibit some hydraulic fractu~ing within the injection horizon around the wellbore because of the nature of the disposal fluids and the potential for high solids content. At such time that a well is converted to fluid disposal, step rate testing will be performed on the Tertiary injection interval to determine the fracture gradient. If the fracture gradient must be exceeded to inject fluids, then additional testing will be performed to ensure that injection or formation fluid will not enter nonexempt freshwater strata. e e SECTION L FORMATION FLUID 20 AAC 25.402(c)(12) 20 AAC 25.252(c)(10) A water analysis for the Tertiary State IIAII is presented as figure L-l. A water analysis for the Tertiary State HBCDII is presented as Figure L-2. A water analysis for the Tertiary State IIEFGII is presented as Figure L-3. 7"j n n I J ' . e FIGURE L-l , CL1-12^ (RI!;V, P.O. IIOX 211'7 . ANCHORAG&:., ALA.teA . CMŒ!\!UCAL& GiEOLOGICAL LABORATORIES Â,,uIUCAN STRATIGRAPHIC COMPANY C'--I WATER ANALYSIS REPORT OPETIATOR WI;LL U 0 FIELD COUNTY STATR. Pan American Petroleum Corp. MGS 11-S 17595 Middle Ground Shoal LAB NO A-630-1 T-8-N, R-l3-W, SM. DATR August 14, 1970 LOCATION. NE SE Sec. 35, FORMATION A Zone INTERV AT SAMPLE FROU Alaska REMARKS lè CONCLUSIONS' Sample taken August 6, 1970. C:ttbns ~ m~/l Anlona mtf/l ~ - Sodium 3382 147.10 Sulfate 4 0.08 P~um 12 0.31 Chlorid. . . - - 3270 92.21 ~cium 7 0.35 ~bonste 396 13.19 Ma~cium - - - - - 4 0.33 Bicarbo=te 2598 42.61 Irc:1 Hydroxide ( ~) Total Cationa 148.09 Total Aniooa 148.09 - - - - Tot:.J. dï;:,olvc:d aolida, mv'l 8355 Specific reåatance @ 68°F.: HaCl ~civ;ùont, rDll/l 7880 Oboerved 0.838 obm-nwton Obeœvc:d pH - - - - - 8.3 Calc:nlqted - - - - 0.83 obm-~ WATER ANALYSIS PATTERN S<:a1c Sample above dcscribed MEQ per Unit N_ Cl 50 Na Ca HC03 5 Ca Mg SO.. 5 Mg Fe C03 5 Fe ( co. Cl HC03 S04 (N. ..Iao Ie ._ vo¡>loa 1acI\HIoo N.. I.. .... 1.1) NOTE: Nc/I=NI11icr_ _ Ii,... Ifoq/l= N~ aqulyaJ.a.. _ 11_ _I.... cIdori4o oqulnl..,=..,. DuaIç . "___ caJaoJ.oúota ..... __.. - . -' - ··~+1.: ?"-::-; . ,.&.) : 'il ",0(-: ~'>~ . ;"'~'.~:-';--t~f.t~ ,if .>- ¡ ·:·_:~t' I '~-';.-' .' '" . 'ë~ i I:.· j.-:, i_,::· k~ f"-'~ ",>. , ~.:~, t--ì "", t ~ ," ¡ j< !.¡. 1< 1'·' !; f~.'· .. I:" ¡.! ., ¡. ; ¡ J f~ " - ~ ¡: F' V I I· 1 !- ,. '. . , ~:..-, r;: ¡;,c i " t ..:. ".-., r .;. b I:' ¡!"~; , . ";'. ., f' ~.;, [:,.. ! ' ,~-,',~.: - :''='" t~:~ r"': ¡-. ....., r',. J. _ , . ¡ í t~· t' I" r~ c, t' . e e FIGURE L-2 CL1.12A (R~. '..~J ~II I \\~-~ ~ ~ P.O. eox a 12:7 . ANCHORAGe. ALAAttA . CHEMICAL & GEOLOGICAL LABORATORIES AMERICAN STRATIGRAPHIC COMPANY (~.) WATER ANALYSIS REPORT OPr:~¡'.TO~ Wi::U, ~¡O FŒLD COUNTY STA*rp' Pan American Petroleum Corp. MGS 11-1 17595 Middle Ground Shoal DATR August 14. 1970 LOCATION . NE SE Sec. FORMATION B. C 8. D INTERV AI. SAMPLE FROU LAB NO A-631-2 35. T-8-N. R-13-W. SM. Zone Alaska P,j3;~J..~~S J: CONCLUSIONS- Sample taken August 5. 1970. C::tkr~ mf{/l ~ Anion. 1n!'!"/l ~ - Scæ= - - - - 3348 145.61 Sulf¡¡ to 18 O_~7 Po~= - - - - - 32 0.95 Chlorid. -. - 3210 90.52 ~ci= 13 0.65 Cubonate 396 13.19 !.:I2~~m - - - - - 6 0.49 Bbrbonate 2660 43.62 Irea Hydroxide ( 147.70 147.70 Tat:l.l C"tio:a - - - - Total An10na - - - - Tatll ~lved solid&, mVl 8333 Specific ro.i&tan.co @ 68·F.: N~Cl oquinl=t, tn¡t/l 7841 O~ed 0.848 ohm-motara o 1x:orveJ. pH - - - - - - - - - - 8.2 Ca1cu1ated - - - - 0.85 ohm-~ WATER ANALYSIS PATTERN Sale MEQ per Unit Szmple above described Na co. n--~ Cl Cl 50 Na HC03 5 Ca SO.. 5 Mg C03' 5 Fe Ca HC03 Mg S04 Fe ( -, (M. ...1_ '" ._ ..... lad...&.. M.. JC. ..4 U) NOTIC: }(c/I=u:DIi........ pc u.... M~I== MI1I1cT- *lw.a1oa<a pc u_ !:odium ch&ori4<o .qw..-.=~ v....s. . H___ .-Iaala_ (,_ _ta · .., ¡,:- ~ _.. Ij' r~!' C,>·_ t·::: ~ ~~. ~ ,- · " ì;:,·· f. ¡.. · · ~.~ " t, t-; t' t·"t.., tL' r' ,.,-"," ',~- , !.~ 1- ¡; .; 1,>- ¡'-'.'." :'1." fIt. ; ~..: I- t': t . ~ [t, a. ;~" ì'> L: ~ - ", i' ; f: f" .- i:'-- t·: ,';';.' '. f~~{- ::..; r..'~ .. rt-: I:." r\·:~','.-·- J": ~ .. t,~ ~;.~: ,""~ :+-:. t·.':--· ·,t· :~"",.; ,'- f", ~.-- ~~ ;' C· ~!: yo,. F:: !.~t' t, t,.. ",,,.". .-,.--....-,y -- ;.<.~~.\~p 6~!:T~~:'~" ~~~"'~;;¿t1~ - CLI.1:::A (i"VJ. 1~"34) e FIGUREL-3 fi' éHF.~,{;r.AT; & GF.OI.OCrCAL LÁÏiÖl1ÁTÔ'RÍÊ§ (.. . ,. . }\.,,[\'\'\ t. t .~" ~J ö, t.' ~'.' ;"\.1' fi t A' 0 '"" I.t '1' ; iO ti ~~l~ t'~L1 ~ t'H e: A~: 1nnUlT 2 G t'U, VI ~ U: C 11) fI-·.U' &Hil Y "'.0. eol<. 2~2Y . ANCHORA.GE. Þ.t.Afi~ . O?~RATO~~"~''''''; r;-'"r""l P,':"·+,)"'û1 P1~~ t.VL;LL :··IO. -~ 1 ;~_~~_..3~~~q~~ (T,~ Cn;-..;¡ ... V1ATER ANALYSIS REPORT LAB NO A-:??!,-? l?Il.:LD____~~·:..:-: -¡..,...~; 1'~-J CC;Tj'r:T~I t;T Ú";""" I ' , .¡.,::~,,",", D..~T~ .T'ir:; _...3, 1.:i69 LOÇ..h;..TIOl~; U~: ;-)~-:: Sf:C. FORMATION E¡? þ .:. (;. INTE:RV A L SAMPLE FROM" 10);(1 :3tr:i.ng -{C; ~ "j't_P_~J fo i~:._l '"':_~-~") Ccnrrl O:':"lF':-r~t,.;= c.:.... ., '~":)~~~'.:J.~.+~5 'Of', T-' j~ t.~~.S ~liZ}¡·tly '-'ìtì'1:-1~r l';~~ht ~r,-:"\ì10~'! f'~l~-,r;)+.r.. IG!i[~r:::P:3 ú: CO¡,¡CLUSIO:·i6- }~'}dr1:r .,...'t:::--;.,.;,... - - ....... (. .'..,'........J" s:1nda f~.t-"";l ô. C::~~-;',.~ Anion." tng:/l 2ß 29);S '36 lì 1;~ ,,,1" ' =-.:!I/l O. r~r 8"3.0S 1.20 SlffÎ.i.l E..:!..! !E;;...~ ~:c-Æ~:!.l ~l~n in 1;~,.R2 P~t.:';$~:;..;:1. n.?? o. Ln fL. ':";t)' c..::J.·;:~ê-.:l ¡--¡ rE2r~7!.~~~ ""-! '¡':'~,::J. L~ ~,.,..~,'::,~-~ ..j ~ l 1 ~6..?1¡ ".rc~ C¡~t10"::2 SuU¡\t<: C-..loridð ~'bom.tc Eic~bo~;2.t~ HydroÚð.c "'7.:.:.rn! T ct.;J Ani£f"nJJ 1 ~(,. ;»\ ".rc.'~ d~~ü3r¡cd üV:;:;;!. 'LJ.:¡/l r'¿.1Cl ..::~ui·.l::J~t, r:~/l Â()c;i: n.? 00..J.ti~i~-d pH S¡µccific r.;·-:.idt:t....~c~ Q GZOI.f..: O~rv(:d C..h:Wz.tc>C\ 0.9? O.9? o:::=ø-~~ o:b.m-~~ Wl..TER ANALYSIS PATTERN S:¡:::nplc ;¡bove d~5cribc:d "J~J~~~[J~11.C¡ f___._,~_.. -.JCco:i".....'.'.'~r.~,~G\Lt . ,~~-...-u1~4.r... b:¡'f:~-h~~j_:l~11.:.;:;.~t\~4~~-. ~~-¡-¡j:j~l ,-1-1 Cï t~t~~~~~:b]~:;::.:7.l±.---:.:;~jj -rti"'1i'~f AttIB HC03 .... !-:=~b~~::~~1_i-:!~~.:::::~~*:~::~~j::t±*? T't·...ttt..::t+-rH-1 t-'~ --t;,-·-".4·~·~_:'J.·.~~.-.l-··"11l""+'¡' ·.Lit:trffi-.......t-l. , 1 ':; ~~l!,~1~!,~~:,,¡t.ili~ SO~ !-~.. ,~_">'4-.~_LL_r.......'·~ ¡'dj~:i;" ...¡.¡ f-- H ;., -~;::¡ ¡E~:~~r~~~~~~~~g~tHßgµg#~t~~ . ....- -- .... ...._""'·-..·of ~"''¿-··-''1-i-''·~''~oI.·i·'''Trl~......!:ti:t!-t.s..-·'t'''¡ Fe ..~~E~;-=~::r:i*R~~"!t-a.PrF'~1ì£1~~~ CO 3 c---,..,.......¡....... --- "-"'---."'-!"';."~:'.-'. r-......~....~~. ÎT"'f"1~...-f-J-I.m-i-"'- Þ---~~~~1:~-~.;:::·::t!q:~~-e~n1~,:¡-:.tJjjttt e--· _..-,--1.......:.~.~ .;.!"..-~....,L~-~r~-r-l-t-.(. t":1"'''''';'' t:.J.4.tl: !~~H~~m} ~?i~fb~1~;î4mJljfrt~m}~i,~ \. l SQ.I~ MEQ per Unit 50 Na 5 Ca 5 Mg 5 Fe Cl HC03 S04 co:) (1-'. ...j~ in .Þn-. :-nph. ¡..dud.. 1-(... 1':... &lIð U) NO"!'~.: J..J"Jl;-..:)..l~ü:;u.c-.. ;on 1,;fC'1" ta...lIl::-.; }.ii.;~n'(¡I <CIQu,i....l.1\t. p""c 1{40_ fh....U"'~..... c;Ù:.)n.~ ~~"'''''''.t=b1' Du~ .. li....."b.c'luM ~1-Î4" ftQQlo 4:~ar. t.J ." r: t ~. .. e e SECTION M Aquifer Exemption 20 AAC 25.402(c)(13) 20 AAC 25.252(c)(11) The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the South Middle Ground Shoal Field are exempted aquifers for Class II injection. (Reference 40 CFR 147.102(b)(2) and 20 AAC 25.440(c).) {?! ì e e SECTION N HYDROCARBON RECOVERY 20 AAC 25.402(c)(14) Incremental hydrocarbon recovery from the South Middle Ground Shoal Field, Platform Dillon, resulting from enhanced recovery waterflood operations is 15.6 MMBO. ~ r e e SECTION 0 MECHANICAL INTEGRITY 20 AAC 25.402(d) and (e) 20 AAC 25.252(d) and (e) In newly drilled South Middle Ground Shoal injection wells, the casing is pressure tested in accordance with 20 AAC 25.030(g). If a producing well is converted to injection, the casing pressure test will be repeated in accordance with 20 AAC 25.412 (c), prior to injection. Thereafter, casing-tubing annulus pressures will be monitored on a regular basis and reported monthly on Form 10-406 in accordance with 20 AAC 25.402(d). All injection wells will be constructed in compliance with mechanical integrity criteria as set forth in 20 AAC 25.252(d) and 20 AAC 25.402(d). 20 AAC 25.402(e) requires immediate notice to the Commission and correc- tive action if the casing-tubing annulus pressure subjects the casing to a hoop stress that exceeds 70 percent of the minimum yield strength of the casing, or if there is more than 200 psi change in the pressure between consecutive pressure readings. Amoco Production Company requests to use the 70 percent limit as the alarm for immediate notice and corrective action. By using the 70 percent yield pressure limit, the injection wells can be monitored to detect leaks and operated safely. Tubing pressure changes and temperature effects during various workover, logging, or testing operations often yield casing-tubing annulus pressure changes greatly exceeding 200 psi. These operations are necessary and occur often during prudent operations. In addition, the annular pressure is sensitive to injection pressures and fluid temperature. Thermal effects and injection rate variation will be a significant controlling factor for casing pressure on water and waste disposal wells. e e SECTION P WELLS WITHIN AREA 20 AAC 25.402(h) 20 AAC 25.252(h) The wells within the South Middle Ground Shoal Field, Platform Dillon are shown on Figure B. To the best of Amoco Production Company·s knowledge, the wells within the area were constructed, and where applicable, abandoned to prevent the movement of fluids into freshwater sources. e . SECTION Q GAS-OIL RATIOS 20 AAC 25.240 (b) & (c)(1) If this application for an Area Injection Order is approved, then a waiver is requested for 20 AAC 25.240(b) requiring no oil well to exceed 100 percent of the original solution gas-oil ratio. The requirement for an oil well to produce at below 100 percent of the original solution gas-oil ratio will not be necessary in accordance wtih 25.240(c)(1) because the pool will have an approved additional recovery project in operation.