Last updated on March 22nd, 2023 at 12:11 am
Title 40 – Protection of Environment–Volume 24
CHAPTER I – ENVIRONMENTAL PROTECTION AGENCY (CONTINUED)
SUBCHAPTER D – WATER PROGRAMS
PARTS 100-103 [RESERVED]
PART 104 – PUBLIC HEARINGS ON EFFLUENT STANDARDS FOR TOXIC POLLUTANTS
§ 104.1 Applicability.
This part shall be applicable to hearings required by statute to be held in connection with the establishment of toxic pollutant effluent standards under section 307(a) of the Act.
§ 104.2 Definitions.
As used in this part, the term:
(a) Act means the Federal Water Pollution Control Act, as amended, 33 U.S.C. 1251 et seq., Public Law 92-500, 86 Stat. 816.
(b) Administrator means the Administrator of the Environmental Protection Agency, or any employee of the Agency to whom the Administrator may by order delegate his authority to carry out his functions under section 307(a) of the Act, or any person who shall by operation of law be authorized to carry out such functions.
(c) Agency means the Environmental Protection Agency.
(d) Hearing Clerk means the Hearing Clerk, U.S. Environmental Protection Agency, 401 M Street SW., Washington, DC 20460.
(e) Party means the Environmental Protection Agency as the proponent of an effluent standard or standards, and any person who files an objection pursuant to § 104.3 hereof.
(f) Person means an individual, corporation, partnership, association, state, municipality or other political subdivision of a state, or any interstate body.
(g) Effluent standard means any effluent standard or limitation, which may include a prohibition of any discharge, established or proposed to be established for any toxic pollutant under section 307(a) of the Act.
(h) Presiding Officer means the Chief Administrative Law Judge of the Agency or a person designated by the Chief Administrative Law Judge or by the Administrator to preside at a hearing under this part, in accordance with § 104.6 hereof.
§ 104.3 Notice of hearing; objection; public comment.
(a) Notice of hearing. Whenever the Administrator publishes any proposed effluent standard, he shall simultaneously publish a notice of a public hearing to be held within thirty days following the date of publication of the proposed standard. Any person who has any objection to a proposed standard may file with the hearing clerk a concise statement of any such objection. No person may participate in the hearing on the proposed toxic pollutant effluent standards unless the hearing clerk has received within 25 days of the publication of the notice of the proposed standards a statement of objection as herein described. In exceptional circumstances and for good cause shown the Presiding Officer may allow an objection to be filed after the filing deadline prescribed in the preceding sentence, which good cause must include at a minimum lack of actual notice on the part of the objector or any representative of such objector of the proposed standards despite his exercise of due diligence, so long as such later filing will not cause undue delay in the proceedings or prejudice to any of the parties.
(b) Objections. Any objection to a proposed standard which is filed pursuant to paragraph (a) of this section shall meet the following requirements:
(1) It shall be filed in triplicate with the hearing clerk within the time prescribed in paragraph (a) of this section;
(2) It shall state concisely and with particularity each portion of the proposed standard to which objection is taken; to the greatest extent feasible it shall state the basis for such objection;
(3) To the greatest extent feasible it shall (i) state specifically the objector’s proposed modification to any such standard proposed by the Agency to which objection is taken, (ii) set forth the reasons why such modification is sought, and (iii) identify and describe the scientific or other basis for such proposed modification, including reference to any pertinent scientific data or authority in support thereof.
(c) Data in support of objection or modification. In the event that the time prescribed for filing objections pursuant to paragraphs (a) and (b) of this section is insufficient to permit an objecting party to fully set forth with such objection the basis therefor together with the information and data specified in paragraph (b)(3) of this section, he may so state at the time of the filing of such objection, and file a more complete statement of such basis, information, and data (hereinafter referred to as “supplemental data”) within the time prescribed by this paragraph (c). The supplemental data herein described shall be filed not later than 40 days following publication of the proposed effluent standards.
(d) Public comment. The notice required under paragraph (a) of this section shall also provide for the submission to the Agency of written comments on the proposed rulemaking by interested persons not filing objections pursuant to this section as hereinabove described, and hence not participating in the hearing as parties. The notice shall fix a time deadline for the submission of such comments which shall be not later than the date set for commencement of the hearing. Such comments shall be received in evidence at the commencement of the hearing. The Administrator in making any decision based upon the record shall take into account the unavailability of cross-examination in determining the weight to be accorded such comments.
(e) Promulgation in absence of objection. If no objection is filed pursuant to this section, then the Administrator shall promulgate the final standards on the basis of the Agency’s statement of basis and purpose and any public comments received pursuant to paragraph (d) of this section.
§ 104.4 Statement of basis and purpose.
Whenever the Administrator publishes a proposed effluent standard, the notice thereof published in the
(a) The purpose of the proposed standard;
(b) An explanation of how the proposed standard was derived;
(c) Scientific and technical data and studies supporting the proposed standard or references thereto if the materials are published or otherwise readily available; and
(d) Such other information as may be reasonably required to set forth fully the basis of the standard.
§ 104.5 Docket and record.
Whenever the Administrator publishes a notice of hearing under this part, the hearing clerk shall promptly establish a docket for the hearing. The docket shall include all written objections filed by any party, any public comments received pursuant to § 104.3(d), a verbatim transcript of the hearing, the statement of basis and purpose required by § 104.4, and any supporting documents referred to therein, and other documents of exhibits that may be received in evidence or marked for identification by or at the direction of the Presiding Officer, or filed by any party in connection with the hearing. Copies of documents in the docket shall be available to any person upon payment to the Agency of such charges as the Agency may prescribe to cover the costs of duplication. The materials contained in the docket shall constitute the record.
§ 104.6 Designation of Presiding Officer.
The Chief Administrative Law Judge of the Agency may preside personally at any hearing under this part, or he may designate another Administrative Law Judge as Presiding Officer for the hearing. In the event of the unavailability of any such Administrative Law Judge, the Administrator may designate a Presiding Officer. No person who has any personal pecuniary interest in the outcome of a proceeding under this part, or who has participated in the development or enforcement of any standard or proposed standard at issue in a proceeding hereunder, shall serve as Presiding Officer in such proceeding.
§ 104.7 Powers of Presiding Officer.
The Presiding Officer shall have the duty to conduct a fair hearing within the time constraints imposed by section 307(a) of the Act. He shall take all necessary action to avoid delay and to maintain order. He shall have all powers necessary to these ends, including but not limited to the power to:
(a) Rule upon motions and requests;
(b) Change the time and place of the hearing, and adjourn the hearing from time to time or from place to place;
(c) Examine and cross-examine witnesses;
(d) Admit or exclude evidence; and
(e) Require any part or all of the evidence to be submitted in writing and by a certain date.
§ 104.8 Prehearing conferences.
Prehearing conferences are encouraged for the purposes of simplification of issues, identification and scheduling of evidence and witnesses, the establishment of an orderly framework for the proceedings, the expediting of the hearing, and such other purposes of a similar nature as may be appropriate.
(a) The Presiding Officer on his own motion may, and at the request of any party made within 20 days of the proposal of standards hereunder shall, direct all parties to appear at a specified time and place for an initial hearing session in the nature of a prehearing conference. Matters taken up at the conference may include, without limitation:
(1) Consideration and simplification of any issues of law or fact;
(2) Identification, advance submission, marking for identification, consideration of any objections to admission, and admission of documentary evidence;
(3) Possible stipulations of fact;
(4) The identification of each witness expected to be called by each party, and the nature and substance of his expected testimony;
(5) Scheduling of witnesses where practicable, and limitation of the number of witnesses where appropriate in order to avoid delay or repetition;
(6) If desirable, the segregation of the hearing into separate segments for different provisions of the proposed effluent standards and the establishment of separate service lists;
(7) Encouragement of objecting parties to agree upon and designate lead counsel for objectors with common interests so as to avoid repetitious questioning of witnesses.
(b) The Presiding Officer may, following a prehearing conference, issue an order setting forth the agreements reached by the parties or representatives, the schedule of witnesses, and a statement of issues for the hearing. In addition such order may direct the parties to file and serve copies of documents or materials, file and serve lists of witnesses which may include a short summary of the expected testimony of each and, in the case of an expert witness, his curriculum vitae, and may contain such other directions as may be appropriate to facilitate the proceedings.
§ 104.9 Admission of evidence.
(a) Where the Presiding Officer has directed identification of witnesses and production of documentation evidence by a certain date, the Presiding Officer may exclude any such evidence, or refuse to allow any witness to testify, when the witness was not identified or the document was not served by the time set by the Presiding Officer. Any such direction with respect to a party’s case in chief shall not preclude the use of such evidence or testimony on rebuttal or response, or upon a showing satisfactory to the Presiding Officer that good cause existed for failure to serve testimony or a document or identify a witness by the time required. The Presiding Officer may require direct testimony to be in writing under oath and served by a certain date, and may exclude testimony not so served.
(b) At the first prehearing conference, or at another time before the beginning of the taking of oral testimony to be set by the Presiding Officer, the statement of basis and purpose, together with any publications or reference materials cited therein, except where excluded by stipulation, shall be received in evidence.
(c) The Presiding Officer may exclude evidence which is immaterial, irrelevant, unduly repetitious or cumulative, or would involve undue delay, or which, if hearsay, is not of the sort upon which responsible persons are accustomed to rely.
(d) If relevant and material evidence is contained in a report or document containing immaterial or irrelevant matter, such immaterial or irrelevant matter may be excluded.
(e) Whenever written testimony or a document or object is excluded from evidence by the Presiding Officer, it shall at the request of the proponent be marked for identification. Where oral testimony is permitted by the Presiding Officer, but the Presiding Officer excludes particular oral testimony, the party offering such testimony may make a brief offer of proof.
(f) Any relevant and material documentary evidence, including but not limited to affidavits, published articles, and official documents, regardless of the availability of the affiant or author for cross-examination, may be admitted in evidence, subject to the provisions of paragraphs (a), (c), and (d) of this section. The availability or nonavailability of cross-examination shall be considered as affecting the weight to be accorded such evidence in any decision based upon the record.
(g) Official notice may be taken by the Presiding Officer or the Administrator of any matter which could be judicially noticed in the United States District Courts, and of other facts within the specialized knowledge and experience of the Agency. Opposing parties shall be given adequate opportunity to show the contrary.
§ 104.10 Hearing procedures.
(a) Following the admission in evidence of the materials described in § 104.9(b), the Agency shall have the right at the commencement of the hearing to supplement that evidence or to introduce additional relevant evidence. Thereafter the evidence of each objector shall be presented in support of its objection and any proposed modification. The Agency staff shall then be given an opportunity to rebut or respond to the objectors’ presentation, including at its option the introduction of evidence which tends to support a standard or standards other than as set forth in the Agency’s own initially proposed standards. In the event that evidence which tends to support such other standard or standards is offered and received in evidence, then the objectors may thereafter rebut or respond to any such new evidence.
(b) The burden of proof as to any modification of any standard proposed by the Agency shall be upon the party who advocates such modification to show that the proposed modification is justified based upon a preponderance of the evidence.
(c) Where necessary in order to prevent undue prolongation of the hearing, or to comply with time limitations set forth in the Act, the Presiding Officer may limit the number of witnesses who may testify, and the scope and extent of cross-examination.
(d) A verbatim transcript of the hearing shall be maintained and shall constitute a part of the record.
(e) If a party objects to the admission or rejection of any evidence or to any other ruling of the Presiding Officer during the hearing, he shall state briefly the grounds of such objection. With respect to any ruling on evidence, it shall not be necessary for any party to claim an exception in order to preserve any right of subsequent review.
(f) Any party may at any time withdraw his objection to a proposed effluent standard.
§ 104.11 Briefs and findings of fact.
At the conclusion of the hearing, the Presiding Officer shall set a schedule for the submission by the parties of briefs and proposed findings of fact and conclusions. In establishing the aforesaid time schedule, the Presiding Officer shall consider the time constraints placed upon the parties and the Administrator by the statutory deadlines.
§ 104.12 Certification of record.
As soon as possible after the hearing, the Presiding Officer shall transmit to the hearing clerk the transcript of the testimony and exhibits introduced in the hearing. The Presiding Officer shall attach to the original transcript his certificate stating that, to the best of his knowledge and belief, the transcript is a true transcript of the testimony given at the hearing except in such particulars as he shall specify, and that the exhibits transmitted are all the exhibits as introduced at the hearing with such exceptions as he shall specify.
§ 104.13 Interlocutory and post-hearing review of rulings of the Presiding Officer; motions.
(a) The Presiding Officer may certify a ruling for interlocutory review by the Administrator where a party so requests and the Presiding Officer concludes that (1) the ruling from which review is sought involves an important question as to which there is substantial ground for difference of opinion, and (2) either (i) a subsequent reversal of his ruling would be likely to result in substantial delay or expense if left to the conclusion of the proceedings, or (ii) a ruling on the question by the Administrator would be of material assistance in expediting the hearing. The certificate shall be in writing and shall specify the material relevant to the ruling certified. If the Administrator determines that interlocutory review is not warranted, he may decline to consider the ruling which has been certified.
(b) Where the Presiding Officer declines to certify a ruling the party who had requested certification may apply to the Administrator for interlocutory review, or the Administrator may on his own motion direct that any matter be submitted to him for review, subject to the standards for review set forth in paragraph (a) of this section. An application for review shall be in writing and shall briefly state the grounds relied on. If the Administrator takes no action with respect to such application for interlocutory review within 15 days of its filing, such application shall be deemed to have been denied.
(c) Unless otherwise ordered by the Presiding Officer or the Administrator, the hearing shall continue pending consideration by the Administrator of any ruling or request for interlocutory review.
(d) Unless otherwise ordered by the Presiding Officer or the Administrator, briefs in response to any application for interlocutory review may be filed by any party within five days of the filing of the application for review.
(e) Failure to request or obtain interlocutory review does not waive the rights of any party to complain of a ruling following completion of the hearing. Within five days following the close of a hearing under this part, any party may apply to the Administrator for post-hearing review of any procedural ruling, or any ruling made by the Presiding Officer concerning the admission or exclusion of evidence to which timely objection was made. Within seven days following the filing of any such application any other party may file a brief in response thereto.
(f) If the Administrator on review under paragraph (e) of this section determines that evidence was improperly excluded, he may order its admission without remand for further proceedings, or may remand with such instructions as he deems appropriate concerning cross-examination, or opportunity for any party to submit further evidence, with respect to such evidence as he directs should be admitted. In making his determination whether to remand, the Administrator shall consider whether the statutory time restraints permit a remand, and whether it would be constructive to allow cross-examination or further evidence with respect to the newly admitted evidence. If evidence is admitted without cross-examination, the Administrator shall consider the lack of opportunity for cross-examination in determining the weight to be given such evidence.
(g) Motions shall be brief, in writing, and may be filed at any time following the publication of the proposed effluent standards, unless otherwise ordered by the Presiding Officer or the Administrator. Unless otherwise ordered or provided in these rules, responses to motions may be filed within seven days of the actual filing of the motion with the hearing clerk.
§ 104.14 Tentative and final decision by the Administrator.
(a) As soon as practicable following the certification of the record and the filing by the parties of briefs and proposed findings of fact and conclusions under § 104.11, the Administrator, with such staff assistance as he deems necessary and appropriate, shall review the entire record and prepare and file a tentative decision based thereon. The tentative decision shall include findings of fact and conclusions, and shall be filed with the hearing clerk who shall at once transmit a copy thereof to each party who participated at the hearing, or his attorney or other representative.
(b) Upon filing of the tentative decision, the Administrator may allow a reasonable time for the parties to file with him any exceptions to the tenative decision, a brief in support of such exceptions containing appropriate references to the record, and any proposed changes in the tentative decision. Such materials shall, upon submission, become part of the record. As soon as practicable after the filing thereof the Administrator shall prepare and file a final decision, copies of which shall be transmitted to the parties or their representatives in the manner prescribed in paragraph (a) of this section.
(c) In the event that the Administrator determines that due and timely execution of his functions, including compliance with time limitations established by law, imperatively and unavoidably so requires, he may omit the preparation and filing of the tentative decision and related procedures set forth in paragraph (b) of this section, and shall instead prepare and file a final decision, copies of which shall be transmitted to the parties or their representatives in the manner prescribed in paragraph (a) of this section.
(d) Any decision rendered by the Administrator pursuant to this section shall include a statement of his findings and conclusions, and the reasons and basis therefor, and shall indicate the toxic pollutant effluent standard or standards which the Administrator is promulgating or intends to promulgate based thereon.
§ 104.15 Promulgation of standards.
Upon consideration of the record, at the time of his final decision the Administrator shall determine whether the proposed effluent standard or standards should be promulgated as proposed, or whether any modification thereof is justified based upon a proponderance of the evidence adduced at the hearing, regardless of whether or not such modification was actually proposed by any objecting party. If he determines that a modification is not justified, he shall promulgate the standard or standards as proposed. If he determines that a modification is justified, he shall promulgate a standard or standards as so modified.
§ 104.16 Filing and time.
(a) All documents or papers required or authorized by the foregoing provisions of this part including, but not limited to, motions, applications for review, and briefs, shall be filed in duplicate with the hearing clerk, except as otherwise expressly provided in these rules. Any document or paper so required or authorized to be filed with the hearing clerk, if it is filed during the course of the hearing, shall be also filed with the Presiding Officer. A copy of each document or paper filed by any party with the Presiding Officer, with the hearing clerk, or with the Administrator shall be served upon all other parties, except to the extent that the list of parties to be so served may be modified by order of the Presiding Officer, and each such document or paper shall be accompanied by a certificate of such service.
(b) A party may be represented in any proceeding under this part by an attorney or other authorized representative. When any document or paper is required under these rules to be served upon a party such service shall be made upon such attorney or other representative.
(c) Except where these rules or an order of the Presiding Officer require receipt of a document by a certain date, any document or paper required or authorized to be filed by this part shall be deemed to be filed when postmarked, or in the case of papers delivered other than by mail, when received by the hearing clerk.
(d) Sundays and legal holidays shall be included in computing the time allowed for the filing of any document or paper, provided, that when such time expires on a Sunday or legal holiday, such period shall be extended to include the next following business day.
PART 105 – RECOGNITION AWARDS UNDER THE CLEAN WATER ACT
General
§ 105.1 Background.
The Environmental Protection Agency’s (EPA) Clean Water Act (CWA) Recognition Awards Program is authorized by CWA section 501(e). The Administrator may provide official recognition to industrial organizations and political subdivisions of States which during the preceding year demonstrated an outstanding technological achievement or an innovative process, method or device in their waste treatment and pollution abatement programs. The wastewater management programs can generally be characterized as waste treatment and/or pollution abatement programs. Individual EPA Regional Administrators (and Regional officials they may designate) also may conduct Regional CWA Recognition Awards Programs according to and consistent with the provisions of this part.
§ 105.2 Definitions.
Applicant means the person authorized to complete the application on behalf of an industrial organization or political subdivision of States.
Application means a completed questionnaire, nomination form, or other documentation submitted to or by the States, EPA Regions or headquarters for consideration of a national CWA Recognition Award.
I means the applicant for an award.
Industrial organization means any company, corporation, association, partnership, firm, university, not-for-profit organization, or wastewater treatment facility, as well as a Federal, State or Tribal government wastewater treatment facility, or U.S. military command to the extent such government and other organizations operate in an “industrial” capacity in the treatment of wastes or abatement of pollution.
Nominee means a candidate recommended by the State or Tribe or EPA for consideration for a CWA Recognition Award.
Political subdivision of State means a municipality, city, town, borough, county, parish, district, association, or other public body (including an intermunicipal agency of two or more of the foregoing entities) created by or pursuant to State law.
State means any of the 50 States, the District of Columbia, the Commonwealth of Puerto Rico, the U.S. Virgin Islands, Guam, American Samoa, and the Commonwealth of Northern Mariana Islands.
State water pollution control agency means the State agency designated by the Governing Authority having responsibility for enforcing State laws relating to the abatement of water pollution.
You means the applicant for an award.
§ 105.3 Title.
The awards are known as the National Clean Water Act Recognition Awards (hereinafter, the Awards Program).
Eligibility Requirements
§ 105.4 What are the requirements for the Awards Program?
(a) EPA will administer the Awards Program, and should establish annual guidance as necessary to administer the Awards Program. EPA will request from the various offices, and States and Tribes as appropriate, nominations for the Awards Program.
(b) Nominees must be in total compliance with all applicable water quality requirements under the CWA in order to be eligible for an award, and otherwise have a satisfactory record with respect to environmental quality.
(c) Nominees must provide written documentation as evidence to support their outstanding technological achievement or innovative process, method or device in their waste treatment and/or pollution abatement programs.
(d) EPA may issue annual guidance memoranda to administer each year’s awards programs. For information on the availability of additional guidance, contact the U.S. Environmental Protection Agency, Municipal Assistance Branch, 1200 Pennsylvania Avenue, NW., Mail Code 4204-M, Washington, DC 20460. You may also visit EPA’s Web site at www.epa.gov/owm.
§ 105.5 Who is eligible to win an award?
A municipality, city, town, borough, county, parish, district, association, government agency, or other public body, (including an intermunicipal agency of two or more of the foregoing entities) created by or pursuant to State law; a company, corporation, association, partnership, firm, university, not-for-profit organization, or wastewater treatment facility, as well as a Federal, State or Tribal government wastewater treatment facility, or U.S. military command to the extent such government and other organizations operate in an industrial capacity in the treatment of wastes or abatement of pollution may be considered for a recognition award.
§ 105.6 What are the Awards Program categories for which I may be eligible?
EPA will publish from time to time, a notice in the
Application and Nomination Process
§ 105.7 How do I apply for an award?
You may contact your local EPA Regional office for information on the Awards Program guidance each year, or check the Web site at http://www.epa.gov/owm/intnet.htm. EPA may use an application or nomination process, as appropriate for the program or Region.
§ 105.8 When can I apply for an award?
You can contact your local EPA Regional office for award submission deadline information which may vary for the award categories, or check the Web site at http://www.epa.gov/owm/intnet.htm.
§ 105.9 How can I get nominated for an award?
You may apply to, or ask your State, Tribe or EPA Region to nominate you for an award. Only applications or nominations recommended by EPA Regions are considered for the national award. EPA personnel conduct compliance evaluations prior to presenting a national award.
Selection Criteria
§ 105.10 What do I need to be considered for an award?
Your facility or pollution abatement program must be in total compliance with all applicable water quality requirements, and otherwise have a satisfactory record with respect to environmental quality. Additionally, your facility or pollution abatement program must provide written documentation as evidence of an outstanding technological achievement or an innovative process, method or device demonstrated in the preceding year, which resulted in environmental benefits, cost savings and/or public acceptance.
§ 105.11 Who selects the award winners?
After EPA receives the completed application, the application is evaluated by a review committee. After the review committee completes its evaluation of the programs that have been nominated, they make recommendations for the national awards. EPA then analyzes the results and selects the award winners.
§ 105.12 How is the awards review committee selected?
EPA review committee members are selected by the EPA and in some cases, State or Tribal water pollution control agencies. The number of participants in a nominations review process is based on staff availability, and may be one person.
§ 105.13 How are the award winners selected?
Nominees and applications are recommended by EPA regions. EPA personnel conduct compliance evaluations prior to presenting a national award. EPA selects national award winners based on demonstrated evidence of outstanding and/or innovative wastewater treatment and pollution abatement programs or projects which result in environmental benefits, cost savings and/or public acceptance. Based upon results of review committee evaluations, the Agency selects first place winners for a national award in the appropriate awards categories. A second place winner may or may not be selected. EPA may or may not select an award winner for every awards program category. Award decisions are not subject to administrative review.
Awards Recognition
§ 105.14 How are award winners notified?
EPA notifies national award winners by letter.
§ 105.15 How are award winners recognized?
EPA presents national award winners with a certificate or plaque at an awards presentation ceremony as recognition for an outstanding technological achievement or an innovative process, method or device in wastewater treatment and/or pollution abatement programs. The President of the United States, the Governor of the State, or Tribal leader of the jurisdiction reservation in which the awardee is situated, the Speaker of the House of Representatives and the President pro tempore of the Senate are notified by the Administrator.
§ 105.16 How are award winners publicized?
EPA announces the annual national recognition award winners through notice published in the
PART 108 – EMPLOYEE PROTECTION HEARINGS
§ 108.1 Applicability.
This part shall be applicable to investigations and hearings required by section 507(e) of the Federal Water Pollution Control Act, as amended, 33 U.S.C. 1251 et seq. (Pub. L. 92-500).
§ 108.2 Definitions.
As used in this part, the term:
(a) Act means the Federal Water Pollution Control Act, as amended;
(b) Effluent limitation means any effluent limitation which is established as a condition of a permit issued or proposed to be issued by a State or by the Environmental Protection Agency pursuant to section 402 of the Act; any toxic or pretreatment effluent standard established under section 307 of the Act; any standard of performance established under section 306 of the Act; and any effluent limitation established under section 302, section 316, or section 318 of the Act.
(c) Order means any order issued by the Administrator under section 309 of the Act; any order issued by a State to secure compliance with a permit, or condition thereof, issued under a program approved pursuant to section 402 of the Act; or any order issued by a court in an action brought pursuant to section 309 or section 505 of the Act.
(d) Party means an employee filing a request under § 108.3, any employee similarly situated, the employer of any such employee, and the Regional Administrator or his designee.
(e) Administrator or Regional Administrator means the Administrator or a Regional Administrator of the Environmental Protection Agency.
§ 108.3 Request for investigation.
Any employee who is discharged or laid-off, threatened with discharge or lay-off, or otherwise discriminated against by any person because of the alleged results of any effluent limitation or order issued under the Act, or any representative of such employee, may submit a request for an investigation under this part to the Regional Administrator of the region in which such discrimination is alleged to have occurred.
§ 108.4 Investigation by Regional Administrator.
Upon receipt of any request meeting the requirements of § 108.3, the Regional Administrator shall conduct a full investigation of the matter, in order to determine whether the request may be related to an effluent limitation or order under the Act. Following the investigation, the Regional Administrator shall notify the employee requesting the investigation (or the employee’s representative) and the employer of such employee, in writing, of his preliminary findings and conclusions. The employee, the representative of such employee, or the employer may within fifteen days following receipt of the preliminary findings and conclusions of the Regional Administrator request a hearing under this part. Upon receipt of such a request, the Regional Administrator, with the concurrence of the Chief Administrative Law Judge, shall publish notice of a hearing to be held not less than 30 days following the date of such publication where he determines that there are factual issues concerning the existence of the alleged discrimination or its relationship to an effluent limitation or order under the Act. The notice shall specify a date before which any party (or representative of such party) may submit a request to appear.
§ 108.5 Procedure.
Any hearing held pursuant to this part shall be of record and shall be conducted according to the requirements of 5 U.S.C. 554. The Administrative Law Judge shall conduct the hearing in an orderly and expeditious manner. By agreement of the parties, he may dismiss the hearing. The Administrative Law Judge, on his own motion, or at the request of any party, shall have the power to hold prehearing conferences, to issue subpoenas for the attendance and testimony of witnesses and the production of relevant papers, books, and documents, and he may administer oaths. The Regional Administrator, and any party submitting a request pursuant to § 108.3 or § 108.4, or counsel or other representative of such party or the Regional Administrator, may appear and offer evidence at the hearing.
§ 108.6 Recommendations.
At the conclusion of any hearing under this part, the Administrative Law Judge shall, based on the record, issue tentative findings of fact and recommendations concerning the alleged discrimination, and shall submit such tentative findings and recommendations to the Administrator. The Administrator shall adopt or modify the findings and recommendations of the Administrative Law Judge, and shall make copies of such findings and recommendations available to the complaining employee, the employer, and the public.
§ 108.7 Hearing before Administrator.
At his option, the Administrator may exercise any powers of an Administrative Law Judge with respect to hearings under this part.
PART 109 – CRITERIA FOR STATE, LOCAL AND REGIONAL OIL REMOVAL CONTINGENCY PLANS
§ 109.1 Applicability.
The criteria in this part are provided to assist State, local and regional agencies in the development of oil removal contingency plans for the inland navigable waters of the United States and all areas other than the high seas, coastal and contiguous zone waters, coastal and Great Lakes ports and harbors and such other areas as may be agreed upon between the Environmental Protection Agency and the Department of Transportation in accordance with section 11(j)(1)(B) of the Federal Act, Executive Order No. 11548 dated July 20, 1970 (35 FR 11677) and § 306.2 of the National Oil and Hazardous Materials Pollution Contingency Plan (35 FR 8511).
§ 109.2 Definitions.
As used in these guidelines, the following terms shall have the meaning indicated below:
(a) Oil means oil of any kind or in any form, including, but not limited to, petroleum, fuel oil, sludge, oil refuse, and oil mixed with wastes other than dredged spoil.
(b) Discharge includes, but is not limited to, any spilling, leaking, pumping, pouring, emitting, emptying, or dumping.
(c) Remove or removal refers to the removal of the oil from the water and shorelines or the taking of such other actions as may be necessary to minimize or mitigate damage to the public health or welfare, including, but not limited to, fish, shellfish, wildlife, and public and private property, shorelines, and beaches.
(d) Major disaster means any hurricane, tornado, storm, flood, high water, wind-driven water, tidal wave, earthquake, drought, fire, or other catastrophe in any part of the United States which, in the determination of the President, is or threatens to become of sufficient severity and magnitude to warrant disaster assistance by the Federal Government to supplement the efforts and available resources of States and local governments and relief organizations in alleviating the damage, loss, hardship, or suffering caused thereby.
(e) United States means the States, the District of Columbia, the Commonwealth of Puerto Rico, the Canal Zone, Guam, American Samoa, the Virgin Islands, and the Trust Territory of the Pacific Islands.
(f) Federal Act means the Federal Water Pollution Control Act, as amended, 33 U.S.C. 1151 et seq.
§ 109.3 Purpose and scope.
The guidelines in this part establish minimum criteria for the development and implementation of State, local, and regional contingency plans by State and local governments in consultation with private interests to insure timely, efficient, coordinated and effective action to minimize damage resulting from oil discharges. Such plans will be directed toward the protection of the public health or welfare of the United States, including, but not limited to, fish, shellfish, wildlife, and public and private property, shorelines, and beaches. The development and implementation of such plans shall be consistent with the National Oil and Hazardous Materials Pollution Contingency Plan. State, local and regional oil removal contingency plans shall provide for the coordination of the total response to an oil discharge so that contingency organizations established thereunder can function independently, in conjunction with each other, or in conjunction with the National and Regional Response Teams established by the National Oil and Hazardous Materials Pollution Contingency Plan.
§ 109.4 Relationship to Federal response actions.
The National Oil and Hazardous Materials Pollution Contingency Plan provides that the Federal on-scene commander shall investigate all reported spills. If such investigation shows that appropriate action is being taken by either the discharger or non-Federal entities, the Federal on-scene commander shall monitor and provide advice or assistance, as required. If appropriate containment or cleanup action is not being taken by the discharger or non-Federal entities, the Federal on-scene commander will take control of the response activity in accordance with section 11(c)(1) of the Federal Act.
§ 109.5 Development and implementation criteria for State, local and regional oil removal contingency plans.
Criteria for the development and implementation of State, local and regional oil removal contingency plans are:
(a) Definition of the authorities, responsibilities and duties of all persons, organizations or agencies which are to be involved or could be involved in planning or directing oil removal operations, with particular care to clearly define the authorities, responsibilities and duties of State and local governmental agencies to avoid unnecessary duplication of contingency planning activities and to minimize the potential for conflict and confusion that could be generated in an emergency situation as a result of such duplications.
(b) Establishment of notification procedures for the purpose of early detection and timely notification of an oil discharge including:
(1) The identification of critical water use areas to facilitate the reporting of and response to oil discharges.
(2) A current list of names, telephone numbers and addresses of the responsible persons and alternates on call to receive notification of an oil discharge as well as the names, telephone numbers and addresses of the organizations and agencies to be notified when an oil discharge is discovered.
(3) Provisions for access to a reliable communications system for timely notification of an oil discharge and incorporation in the communications system of the capability for interconnection with the communications systems established under related oil removal contingency plans, particularly State and National plans.
(4) An established, prearranged procedure for requesting assistance during a major disaster or when the situation exceeds the response capability of the State, local or regional authority.
(c) Provisions to assure that full resource capability is known and can be committed during an oil discharge situation including:
(1) The identification and inventory of applicable equipment, materials and supplies which are available locally and regionally.
(2) An estimate of the equipment, materials and supplies which would be required to remove the maximum oil discharge to be anticipated.
(3) Development of agreements and arrangements in advance of an oil discharge for the acquisition of equipment, materials and supplies to be used in responding to such a discharge.
(d) Provisions for well defined and specific actions to be taken after discovery and notification of an oil discharge including:
(1) Specification of an oil discharge response operating team consisting of trained, prepared and available operating personnel.
(2) Predesignation of a properly qualified oil discharge response coordinator who is charged with the responsibility and delegated commensurate authority for directing and coordinating response operations and who knows how to request assistance from Federal authorities operating under existing national and regional contingency plans.
(3) A preplanned location for an oil discharge response operations center and a reliable communications system for directing the coordinated overall response operations.
(4) Provisions for varying degrees of response effort depending on the severity of the oil discharge.
(5) Specification of the order of priority in which the various water uses are to be protected where more than one water use may be adversely affected as a result of an oil discharge and where response operations may not be adequate to protect all uses.
(e) Specific and well defined procedures to facilitate recovery of damages and enforcement measures as provided for by State and local statutes and ordinances.
§ 109.6 Coordination.
For the purposes of coordination, the contingency plans of State and local governments should be developed and implemented in consultation with private interests. A copy of any oil removal contingency plan developed by State and local governments should be forwarded to the Council on Environmental Quality upon request to facilitate the coordination of these contingency plans with the National Oil and Hazardous Materials Pollution Contingency Plan.
PART 110 – DISCHARGE OF OIL
§ 110.1 Definitions.
Terms not defined in this section have the same meaning given by the Section 311 of the Act. As used in this part, the following terms shall have the meaning indicated below:
Act means the Federal Water Pollution Control Act, as amended, 33 U.S.C. 1251 et seq., also known as the Clean Water Act;
Administrator means the Administrator of the Environmental Protection Agency (EPA);
Applicable water quality standards means State water quality standards adopted by the State pursuant to section 303 of the Act or promulgated by EPA pursuant to that section;
MARPOL 73/78 means the International Convention for the Prevention of Pollution from Ships, 1973, as modified by the Protocol of 1978 relating thereto, Annex I, which regulates pollution from oil and which entered into force on October 2, 1983;
Navigable waters means waters of the United States, including the territorial seas, as defined in § 120.2 of this chapter.
NPDES means National Pollutant Discharge Elimination System;
Sheen means an iridescent appearance on the surface of water;
Sludge means an aggregate of oil or oil and other matter of any kind in any form other than dredged spoil having a combined specific gravity equivalent to or greater than water;
United States means the States, the District of Columbia, the Commonwealth of Puerto Rico, Guam, American Samoa, the Virgin Islands, and the Trust Territory of the Pacific Islands;
§ 110.2 Applicability.
The regulations of this part apply to the discharge of oil prohibited by section 311(b)(3) of the Act.
§ 110.3 Discharge of oil in such quantities as “may be harmful” pursuant to section 311(b)(4) of the Act.
For purposes of section 311(b)(4) of the Act, discharges of oil in such quantities that the Administrator has determined may be harmful to the public health or welfare or the environment of the United States include discharges of oil that:
(a) Violate applicable water quality standards; or
(b) Cause a film or sheen upon or discoloration of the surface of the water or adjoining shorelines or cause a sludge or emulsion to be deposited beneath the surface of the water or upon adjoining shorelines.
§ 110.4 Dispersants.
Addition of dispersants or emulsifiers to oil to be discharged that would circumvent the provisions of this part is prohibited.
§ 110.5 Discharges of oil not determined “as may be harmful” pursuant to Section 311(b)(3) of the Act.
Notwithstanding any other provisions of this part, the Administrator has not determined the following discharges of oil “as may be harmful” for purposes of section 311(b) of the Act:
(a) Discharges of oil from a properly functioning vessel engine (including an engine on a public vessel) and any discharges of such oil accumulated in the bilges of a vessel discharged in compliance with MARPOL 73/78, Annex I, as provided in 33 CFR part 151, subpart A;
(b) Other discharges of oil permitted under MARPOL 73/78, Annex I, as provided in 33 CFR part 151, subpart A; and
(c) Any discharge of oil explicitly permitted by the Administrator in connection with research, demonstration projects, or studies relating to the prevention, control, or abatement of oil pollution.
§ 110.6 Notice.
Any person in charge of a vessel or of an onshore or offshore facility shall, as soon as he or she has knowledge of any discharge of oil from such vessel or facility in violation of section 311(b)(3) of the Act, immediately notify the National Response Center (NRC) (800-424-8802; in the Washington, DC metropolitan area, 202-426-2675). If direct reporting to the NRC is not practicable, reports may be made to the Coast Guard or EPA predesignated On-Scene Coordinator (OSC) for the geographic area where the discharge occurs. All such reports shall be promptly relayed to the NRC. If it is not possible to notify the NRC or the predesignated OCS immediately, reports may be made immediately to the nearest Coast Guard unit, provided that the person in charge of the vessel or onshore or offshore facility notifies the NRC as soon as possible. The reports shall be made in accordance with such procedures as the Secretary of Transportation may prescribe. The procedures for such notice are set forth in U.S. Coast Guard regulations, 33 CFR part 153, subpart B and in the National Oil and Hazardous Substances Pollution Contingency Plan, 40 CFR part 300, subpart E.
PART 112 – OIL POLLUTION PREVENTION
Subpart A – Applicability, Definitions, and General Requirements for All Facilities and All Types of Oils
§ 112.1 General applicability.
(a)(1) This part establishes procedures, methods, equipment, and other requirements to prevent the discharge of oil from non-transportation-related onshore and offshore facilities into or upon the navigable waters of the United States or adjoining shorelines, or into or upon the waters of the contiguous zone, or in connection with activities under the Outer Continental Shelf Lands Act or the Deepwater Port Act of 1974, or that may affect natural resources belonging to, appertaining to, or under the exclusive management authority of the United States (including resources under the Magnuson Fishery Conservation and Management Act).
(2) As used in this part, words in the singular also include the plural and words in the masculine gender also include the feminine and vice versa, as the case may require.
(b) Except as provided in paragraph (d) of this section, this part applies to any owner or operator of a non-transportation-related onshore or offshore facility engaged in drilling, producing, gathering, storing, processing, refining, transferring, distributing, using, or consuming oil and oil products, which due to its location, could reasonably be expected to discharge oil in quantities that may be harmful, as described in part 110 of this chapter, into or upon the navigable waters of the United States or adjoining shorelines, or into or upon the waters of the contiguous zone, or in connection with activities under the Outer Continental Shelf Lands Act or the Deepwater Port Act of 1974, or that may affect natural resources belonging to, appertaining to, or under the exclusive management authority of the United States (including resources under the Magnuson Fishery Conservation and Management Act) that has oil in:
(1) Any aboveground container;
(2) Any completely buried tank as defined in § 112.2;
(3) Any container that is used for standby storage, for seasonal storage, or for temporary storage, or not otherwise “permanently closed” as defined in § 112.2;
(4) Any “bunkered tank” or “partially buried tank” as defined in § 112.2, or any container in a vault, each of which is considered an aboveground storage container for purposes of this part.
(c) As provided in section 313 of the Clean Water Act (CWA), departments, agencies, and instrumentalities of the Federal government are subject to this part to the same extent as any person.
(d) Except as provided in paragraph (f) of this section, this part does not apply to:
(1) The owner or operator of any facility, equipment, or operation that is not subject to the jurisdiction of the Environmental Protection Agency (EPA) under section 311(j)(1)(C) of the CWA, as follows:
(i) Any onshore or offshore facility, that due to its location, could not reasonably be expected to have a discharge as described in paragraph (b) of this section. This determination must be based solely upon consideration of the geographical and location aspects of the facility (such as proximity to navigable waters or adjoining shorelines, land contour, drainage, etc.) and must exclude consideration of manmade features such as dikes, equipment or other structures, which may serve to restrain, hinder, contain, or otherwise prevent a discharge as described in paragraph (b) of this section.
(ii) Any equipment, or operation of a vessel or transportation-related onshore or offshore facility which is subject to the authority and control of the U.S. Department of Transportation, as defined in the Memorandum of Understanding between the Secretary of Transportation and the Administrator of EPA, dated November 24, 1971 (appendix A of this part).
(iii) Any equipment, or operation of a vessel or onshore or offshore facility which is subject to the authority and control of the U.S. Department of Transportation or the U.S. Department of the Interior, as defined in the Memorandum of Understanding between the Secretary of Transportation, the Secretary of the Interior, and the Administrator of EPA, dated November 8, 1993 (appendix B of this part).
(2) Any facility which, although otherwise subject to the jurisdiction of EPA, meets both of the following requirements:
(i) The completely buried storage capacity of the facility is 42,000 U.S. gallons or less of oil. For purposes of this exemption, the completely buried storage capacity of a facility excludes the capacity of a completely buried tank, as defined in § 112.2, and connected underground piping, underground ancillary equipment, and containment systems, that is currently subject to all of the technical requirements of part 280 of this chapter or all of the technical requirements of a State program approved under part 281 of this chapter, or the capacity of any underground oil storage tanks deferred under 40 CFR part 280 that supply emergency diesel generators at a nuclear power generation facility licensed by the Nuclear Regulatory Commission and subject to any Nuclear Regulatory Commission provision regarding design and quality criteria, including, but not limited to, 10 CFR part 50. The completely buried storage capacity of a facility also excludes the capacity of a container that is “permanently closed,” as defined in § 112.2 and the capacity of intra-facility gathering lines subject to the regulatory requirements of 49 CFR part 192 or 195.
(ii) The aggregate aboveground storage capacity of the facility is 1,320 U.S. gallons or less of oil. For the purposes of this exemption, only containers with a capacity of 55 U.S. gallons or greater are counted. The aggregate aboveground storage capacity of a facility excludes:
(A) The capacity of a container that is “permanently closed” as defined in § 112.2;
(B) The capacity of a “motive power container” as defined in § 112.2;
(C) The capacity of hot-mix asphalt or any hot-mix asphalt container;
(D) The capacity of a container for heating oil used solely at a single-family residence;
(E) The capacity of pesticide application equipment and related mix containers.
(F) The capacity of any milk and milk product container and associated piping and appurtenances.
(3) Any offshore oil drilling, production, or workover facility that is subject to the notices and regulations of the Minerals Management Service, as specified in the Memorandum of Understanding between the Secretary of Transportation, the Secretary of the Interior, and the Administrator of EPA, dated November 8, 1993 (appendix B of this part).
(4) Any completely buried storage tank, as defined in § 112.2, and connected underground piping, underground ancillary equipment, and containment systems, at any facility, that is subject to all of the technical requirements of part 280 of this chapter or a State program approved under part 281 of this chapter, or any underground oil storage tanks including below-grade vaulted tanks, deferred under 40 CFR part 280, as originally promulgated, that supply emergency diesel generators at a nuclear power generation facility licensed by the Nuclear Regulatory Commission, provided that such a tank is subject to any Nuclear Regulatory Commission provision regarding design and quality criteria, including, but not limited to, 10 CFR part 50. Such emergency generator tanks must be marked on the facility diagram as provided in § 112.7(a)(3), if the facility is otherwise subject to this part.
(5) Any container with a storage capacity of less than 55 gallons of oil.
(6) Any facility or part thereof used exclusively for wastewater treatment and not used to satisfy any requirement of this part. The production, recovery, or recycling of oil is not wastewater treatment for purposes of this paragraph.
(7) Any “motive power container,” as defined in § 112.2. The transfer of fuel or other oil into a motive power container at an otherwise regulated facility is not eligible for this exemption.
(8) Hot-mix asphalt, or any hot-mix asphalt container.
(9) Any container for heating oil used solely at a single-family residence.
(10) Any pesticide application equipment or related mix containers.
(11) Intra-facility gathering lines subject to the regulatory requirements of 49 CFR part 192 or 195, except that such a line’s location must be identified and marked as “exempt” on the facility diagram as provided in § 112.7(a)(3), if the facility is otherwise subject to this part.
(12) Any milk and milk product container and associated piping and appurtenances.
(e) This part establishes requirements for the preparation and implementation of Spill Prevention, Control, and Countermeasure (SPCC) Plans. SPCC Plans are designed to complement existing laws, regulations, rules, standards, policies, and procedures pertaining to safety standards, fire prevention, and pollution prevention rules. The purpose of an SPCC Plan is to form a comprehensive Federal/State spill prevention program that minimizes the potential for discharges. The SPCC Plan must address all relevant spill prevention, control, and countermeasures necessary at the specific facility. Compliance with this part does not in any way relieve the owner or operator of an onshore or an offshore facility from compliance with other Federal, State, or local laws.
(f) Notwithstanding paragraph (d) of this section, the Regional Administrator may require that the owner or operator of any facility subject to the jurisdiction of EPA under section 311(j) of the CWA prepare and implement an SPCC Plan, or any applicable part, to carry out the purposes of the CWA.
(1) Following a preliminary determination, the Regional Administrator must provide a written notice to the owner or operator stating the reasons why he must prepare an SPCC Plan, or applicable part. The Regional Administrator must send such notice to the owner or operator by certified mail or by personal delivery. If the owner or operator is a corporation, the Regional Administrator must also mail a copy of such notice to the registered agent, if any and if known, of the corporation in the State where the facility is located.
(2) Within 30 days of receipt of such written notice, the owner or operator may provide information and data and may consult with the Agency about the need to prepare an SPCC Plan, or applicable part.
(3) Within 30 days following the time under paragraph (b)(2) of this section within which the owner or operator may provide information and data and consult with the Agency about the need to prepare an SPCC Plan, or applicable part, the Regional Administrator must make a final determination regarding whether the owner or operator is required to prepare and implement an SPCC Plan, or applicable part. The Regional Administrator must send the final determination to the owner or operator by certified mail or by personal delivery. If the owner or operator is a corporation, the Regional Administrator must also mail a copy of the final determination to the registered agent, if any and if known, of the corporation in the State where the facility is located.
(4) If the Regional Administrator makes a final determination that an SPCC Plan, or applicable part, is necessary, the owner or operator must prepare the Plan, or applicable part, within six months of that final determination and implement the Plan, or applicable part, as soon as possible, but not later than one year after the Regional Administrator has made a final determination.
(5) The owner or operator may appeal a final determination made by the Regional Administrator requiring preparation and implementation of an SPCC Plan, or applicable part, under this paragraph. The owner or operator must make the appeal to the Administrator of EPA within 30 days of receipt of the final determination under paragraph (b)(3) of this section from the Regional Administrator requiring preparation and/or implementation of an SPCC Plan, or applicable part. The owner or operator must send a complete copy of the appeal to the Regional Administrator at the time he makes the appeal to the Administrator. The appeal must contain a clear and concise statement of the issues and points of fact in the case. In the appeal, the owner or operator may also provide additional information. The additional information may be from any person. The Administrator may request additional information from the owner or operator. The Administrator must render a decision within 60 days of receiving the appeal or additional information submitted by the owner or operator and must serve the owner or operator with the decision made in the appeal in the manner described in paragraph (f)(1) of this section.
§ 112.2 Definitions.
For the purposes of this part:
Adverse weather means weather conditions that make it difficult for response equipment and personnel to clean up or remove spilled oil, and that must be considered when identifying response systems and equipment in a response plan for the applicable operating environment. Factors to consider include significant wave height as specified in appendix E to this part (as appropriate), ice conditions, temperatures, weather-related visibility, and currents within the area in which the systems or equipment is intended to function.
Alteration means any work on a container involving cutting, burning, welding, or heating operations that changes the physical dimensions or configuration of the container.
Animal fat means a non-petroleum oil, fat, or grease of animal, fish, or marine mammal origin.
Breakout tank means a container used to relieve surges in an oil pipeline system or to receive and store oil transported by a pipeline for reinjection and continued transportation by pipeline.
Bulk storage container means any container used to store oil. These containers are used for purposes including, but not limited to, the storage of oil prior to use, while being used, or prior to further distribution in commerce. Oil-filled electrical, operating, or manufacturing equipment is not a bulk storage container.
Bunkered tank means a container constructed or placed in the ground by cutting the earth and re-covering the container in a manner that breaks the surrounding natural grade, or that lies above grade, and is covered with earth, sand, gravel, asphalt, or other material. A bunkered tank is considered an aboveground storage container for purposes of this part.
Completely buried tank means any container completely below grade and covered with earth, sand, gravel, asphalt, or other material. Containers in vaults, bunkered tanks, or partially buried tanks are considered aboveground storage containers for purposes of this part.
Complex means a facility possessing a combination of transportation-related and non-transportation-related components that is subject to the jurisdiction of more than one Federal agency under section 311(j) of the CWA.
Contiguous zone means the zone established by the United States under Article 24 of the Convention of the Territorial Sea and Contiguous Zone, that is contiguous to the territorial sea and that extends nine miles seaward from the outer limit of the territorial area.
Contract or other approved means means:
(1) A written contractual agreement with an oil spill removal organization that identifies and ensures the availability of the necessary personnel and equipment within appropriate response times; and/or
(2) A written certification by the owner or operator that the necessary personnel and equipment resources, owned or operated by the facility owner or operator, are available to respond to a discharge within appropriate response times; and/or
(3) Active membership in a local or regional oil spill removal organization that has identified and ensures adequate access through such membership to necessary personnel and equipment to respond to a discharge within appropriate response times in the specified geographic area; and/or
(4) Any other specific arrangement approved by the Regional Administrator upon request of the owner or operator.
Discharge includes, but is not limited to, any spilling, leaking, pumping, pouring, emitting, emptying, or dumping of oil, but excludes discharges in compliance with a permit under section 402 of the CWA; discharges resulting from circumstances identified, reviewed, and made a part of the public record with respect to a permit issued or modified under section 402 of the CWA, and subject to a condition in such permit; or continuous or anticipated intermittent discharges from a point source, identified in a permit or permit application under section 402 of the CWA, that are caused by events occurring within the scope of relevant operating or treatment systems. For purposes of this part, the term discharge shall not include any discharge of oil that is authorized by a permit issued under section 13 of the River and Harbor Act of 1899 (33 U.S.C. 407).
Facility means any mobile or fixed, onshore or offshore building, property, parcel, lease, structure, installation, equipment, pipe, or pipeline (other than a vessel or a public vessel) used in oil well drilling operations, oil production, oil refining, oil storage, oil gathering, oil processing, oil transfer, oil distribution, and oil waste treatment, or in which oil is used, as described in appendix A to this part. The boundaries of a facility depend on several site-specific factors, including but not limited to, the ownership or operation of buildings, structures, and equipment on the same site and types of activity at the site. Contiguous or non-contiguous buildings, properties, parcels, leases, structures, installations, pipes, or pipelines under the ownership or operation of the same person may be considered separate facilities. Only this definition governs whether a facility is subject to this part.
Farm means a facility on a tract of land devoted to the production of crops or raising of animals, including fish, which produced and sold, or normally would have produced and sold, $1,000 or more of agricultural products during a year.
Fish and wildlife and sensitive environments means areas that may be identified by their legal designation or by evaluations of Area Committees (for planning) or members of the Federal On-Scene Coordinator’s spill response structure (during responses). These areas may include wetlands, National and State parks, critical habitats for endangered or threatened species, wilderness and natural resource areas, marine sanctuaries and estuarine reserves, conservation areas, preserves, wildlife areas, wildlife refuges, wild and scenic rivers, recreational areas, national forests, Federal and State lands that are research national areas, heritage program areas, land trust areas, and historical and archaeological sites and parks. These areas may also include unique habitats such as aquaculture sites and agricultural surface water intakes, bird nesting areas, critical biological resource areas, designated migratory routes, and designated seasonal habitats.
Injury means a measurable adverse change, either long- or short-term, in the chemical or physical quality or the viability of a natural resource resulting either directly or indirectly from exposure to a discharge, or exposure to a product of reactions resulting from a discharge.
Loading/unloading rack means a fixed structure (such as a platform, gangway) necessary for loading or unloading a tank truck or tank car, which is located at a facility subject to the requirements of this part. A loading/unloading rack includes a loading or unloading arm, and may include any combination of the following: piping assemblages, valves, pumps, shut-off devices, overfill sensors, or personnel safety devices.
Maximum extent practicable means within the limitations used to determine oil spill planning resources and response times for on-water recovery, shoreline protection, and cleanup for worst case discharges from onshore non-transportation-related facilities in adverse weather. It includes the planned capability to respond to a worst case discharge in adverse weather, as contained in a response plan that meets the requirements in § 112.20 or in a specific plan approved by the Regional Administrator.
Mobile refueler means a bulk storage container onboard a vehicle or towed, that is designed or used solely to store and transport fuel for transfer into or from an aircraft, motor vehicle, locomotive, vessel, ground service equipment, or other oil storage container.
Motive power container means any onboard bulk storage container used primarily to power the movement of a motor vehicle, or ancillary onboard oil-filled operational equipment. An onboard bulk storage container which is used to store or transfer oil for further distribution is not a motive power container. The definition of motive power container does not include oil drilling or workover equipment, including rigs.
Navigable waters means waters of the United States, including the territorial seas, as defined in § 120.2 of this chapter.
Non-petroleum oil means oil of any kind that is not petroleum-based, including but not limited to: Fats, oils, and greases of animal, fish, or marine mammal origin; and vegetable oils, including oils from seeds, nuts, fruits, and kernels.
Offshore facility means any facility of any kind (other than a vessel or public vessel) located in, on, or under any of the navigable waters of the United States, and any facility of any kind that is subject to the jurisdiction of the United States and is located in, on, or under any other waters.
Oil means oil of any kind or in any form, including, but not limited to: fats, oils, or greases of animal, fish, or marine mammal origin; vegetable oils, including oils from seeds, nuts, fruits, or kernels; and, other oils and greases, including petroleum, fuel oil, sludge, synthetic oils, mineral oils, oil refuse, or oil mixed with wastes other than dredged spoil.
Oil-filled operational equipment means equipment that includes an oil storage container (or multiple containers) in which the oil is present solely to support the function of the apparatus or the device. Oil-filled operational equipment is not considered a bulk storage container, and does not include oil-filled manufacturing equipment (flow-through process). Examples of oil-filled operational equipment include, but are not limited to, hydraulic systems, lubricating systems (e.g., those for pumps, compressors and other rotating equipment, including pumpjack lubrication systems), gear boxes, machining coolant systems, heat transfer systems, transformers, circuit breakers, electrical switches, and other systems containing oil solely to enable the operation of the device.
Oil Spill Removal Organization means an entity that provides oil spill response resources, and includes any for-profit or not-for-profit contractor, cooperative, or in-house response resources that have been established in a geographic area to provide required response resources.
Onshore facility means any facility of any kind located in, on, or under any land within the United States, other than submerged lands.
Owner or operator means any person owning or operating an onshore facility or an offshore facility, and in the case of any abandoned offshore facility, the person who owned or operated or maintained the facility immediately prior to such abandonment.
Partially buried tank means a storage container that is partially inserted or constructed in the ground, but not entirely below grade, and not completely covered with earth, sand, gravel, asphalt, or other material. A partially buried tank is considered an aboveground storage container for purposes of this part.
Permanently closed means any container or facility for which:
(1) All liquid and sludge has been removed from each container and connecting line; and
(2) All connecting lines and piping have been disconnected from the container and blanked off, all valves (except for ventilation valves) have been closed and locked, and conspicuous signs have been posted on each container stating that it is a permanently closed container and noting the date of closure.
Person includes an individual, firm, corporation, association, or partnership.
Petroleum oil means petroleum in any form, including but not limited to crude oil, fuel oil, mineral oil, sludge, oil refuse, and refined products.
Produced water container means a storage container at an oil production facility used to store the produced water after initial oil/water separation, and prior to reinjection, beneficial reuse, discharge, or transfer for disposal.
Production facility means all structures (including but not limited to wells, platforms, or storage facilities), piping (including but not limited to flowlines or intra-facility gathering lines), or equipment (including but not limited to workover equipment, separation equipment, or auxiliary non-transportation-related equipment) used in the production, extraction, recovery, lifting, stabilization, separation or treating of oil (including condensate), or associated storage or measurement, and is located in an oil or gas field, at a facility. This definition governs whether such structures, piping, or equipment are subject to a specific section of this part.
Regional Administrator means the Regional Administrator of the Environmental Protection Agency, in and for the Region in which the facility is located.
Repair means any work necessary to maintain or restore a container to a condition suitable for safe operation, other than that necessary for ordinary, day-to-day maintenance to maintain the functional integrity of the container and that does not weaken the container.
Spill Prevention, Control, and Countermeasure Plan; SPCC Plan, or Plan means the document required by § 112.3 that details the equipment, workforce, procedures, and steps to prevent, control, and provide adequate countermeasures to a discharge.
Storage capacity of a container means the shell capacity of the container.
Transportation-related and non-transportation-related, as applied to an onshore or offshore facility, are defined in the Memorandum of Understanding between the Secretary of Transportation and the Administrator of the Environmental Protection Agency, dated November 24, 1971, (appendix A of this part).
United States means the States, the District of Columbia, the Commonwealth of Puerto Rico, the Commonwealth of the Northern Mariana Islands, Guam, American Samoa, the U.S. Virgin Islands, and the Pacific Island Governments.
Vegetable oil means a non-petroleum oil or fat of vegetable origin, including but not limited to oils and fats derived from plant seeds, nuts, fruits, and kernels.
Vessel means every description of watercraft or other artificial contrivance used, or capable of being used, as a means of transportation on water, other than a public vessel.
Worst case discharge for an on-shore non-transportation related facility means the largest foreseeable discharge in adverse weather conditions as determined using the worksheets in Appendix D to this part.
§ 112.3 Requirement to prepare and implement a Spill Prevention, Control, and Countermeasure Plan.
The owner or operator or an onshore or offshore facility subject to this section must prepare in writing and implement a Spill Prevention Control and Countermeasure Plan (hereafter “SPCC Plan” or “Plan”),” in accordance with § 112.7 and any other applicable section of this part.
(a)(1) Except as otherwise provided in this section, if your facility, or mobile or portable facility, was in operation on or before August 16, 2002, you must maintain your Plan, but must amend it, if necessary to ensure compliance with this part, and implement the amended Plan no later than November 10, 2011. If such a facility becomes operational after August 16, 2002, through November 10, 2011, and could reasonably be expected to have a discharge as described in § 112.1(b), you must prepare and implement a Plan on or before November 10, 2011. If such a facility (excluding oil production facilities) becomes operational after November 10, 2011, and could reasonably be expected to have a discharge as described in § 112.1(b), you must prepare and implement a Plan before you begin operations. You are not required to prepare a new Plan each time you move a mobile or portable facility to a new site; the Plan may be general. When you move the mobile or portable facility, you must locate and install it using the discharge prevention practices outlined in the Plan for the facility. The Plan is applicable only while the mobile or portable facility is in a fixed (non-transportation) operating mode.
(2) If your drilling, production or workover facility, including a mobile or portable facility, is offshore or has an offshore component; or your onshore facility is required to have and submit a Facility Response Plan pursuant to 40 CFR 112.20(a), and was in operation on or before August 16, 2002, you must maintain your Plan, but must amend it, if necessary to ensure compliance with this part, and implement the amended Plan no later than November 10, 2010. If such a facility becomes operational after August 16, 2002, through November 10, 2010, and could reasonably be expected to have a discharge as described in § 112.1(b), you must prepare and implement a Plan on or before November 10, 2010. If such a facility (excluding oil production facilities) becomes operational after November 10, 2010, and could reasonably be expected to have a discharge as described in § 112.1(b), you must prepare and implement a Plan before you begin operations. You are not required to prepare a new Plan each time you move a mobile or portable facility to a new site; the Plan may be general. When you move the mobile or portable facility, you must locate and install it using the discharge prevention practices outlined in the Plan for the facility. The Plan is applicable only while the mobile or portable facility is in a fixed (non-transportation) operating mode.
(3) If your farm, as defined in § 112.2, was in operation on or before August 16, 2002, you must maintain your Plan, but must amend it, if necessary to ensure compliance with this part, and implement the amended Plan on or before May 10, 2013. If your farm becomes operational after August 16, 2002, through May 10, 2013, and could reasonably be expected to have a discharge as described in § 112.1(b), you must prepare and implement a Plan on or before May 10, 2013. If your farm becomes operational after May 10, 2013, and could reasonably be expected to have a discharge as described in § 112.1(b), you must prepare and implement a Plan before you begin operations.
(b) If your oil production facility as described in paragraph (a)(1) of this section becomes operational after November 10, 2011, or as described in paragraph (a)(2) of this section becomes operational after November 10, 2010, and could reasonably be expected to have a discharge as described in § 112.1(b), you must prepare and implement a Plan within six months after you begin operations.
(c) [Reserved]
(d) Except as provided in § 112.6, a licensed Professional Engineer must review and certify a Plan for it to be effective to satisfy the requirements of this part.
(1) By means of this certification the Professional Engineer attests:
(i) That he is familiar with the requirements of this part ;
(ii) That he or his agent has visited and examined the facility;
(iii) That the Plan has been prepared in accordance with good engineering practice, including consideration of applicable industry standards, and with the requirements of this part;
(iv) That procedures for required inspections and testing have been established; and
(v) That the Plan is adequate for the facility.
(vi) That, if applicable, for a produced water container subject to § 112.9(c)(6), any procedure to minimize the amount of free-phase oil is designed to reduce the accumulation of free-phase oil and the procedures and frequency for required inspections, maintenance and testing have been established and are described in the Plan.
(2) Such certification shall in no way relieve the owner or operator of a facility of his duty to prepare and fully implement such Plan in accordance with the requirements of this part.
(e) If you are the owner or operator of a facility for which a Plan is required under this section, you must:
(1) Maintain a complete copy of the Plan at the facility if the facility is normally attended at least four hours per day, or at the nearest field office if the facility is not so attended, and
(2) Have the Plan available to the Regional Administrator for on-site review during normal working hours.
(f) Extension of time. (1) The Regional Administrator may authorize an extension of time for the preparation and full implementation of a Plan, or any amendment thereto, beyond the time permitted for the preparation, implementation, or amendment of a Plan under this part, when he finds that the owner or operator of a facility subject to this section, cannot fully comply with the requirements as a result of either nonavailability of qualified personnel, or delays in construction or equipment delivery beyond the control and without the fault of such owner or operator or his agents or employees.
(2) If you are an owner or operator seeking an extension of time under paragraph (f)(1) of this section, you may submit a written extension request to the Regional Administrator. Your request must include:
(i) A full explanation of the cause for any such delay and the specific aspects of the Plan affected by the delay;
(ii) A full discussion of actions being taken or contemplated to minimize or mitigate such delay; and
(iii) A proposed time schedule for the implementation of any corrective actions being taken or contemplated, including interim dates for completion of tests or studies, installation and operation of any necessary equipment, or other preventive measures. In addition you may present additional oral or written statements in support of your extension request.
(3) The submission of a written extension request under paragraph (f)(2) of this section does not relieve you of your obligation to comply with the requirements of this part. The Regional Administrator may request a copy of your Plan to evaluate the extension request. When the Regional Administrator authorizes an extension of time for particular equipment or other specific aspects of the Plan, such extension does not affect your obligation to comply with the requirements related to other equipment or other specific aspects of the Plan for which the Regional Administrator has not expressly authorized an extension.
(g) Qualified Facilities. The owner or operator of a qualified facility as defined in this subparagraph may self-certify his facility’s Plan, as provided in § 112.6. A qualified facility is one that meets the following Tier I or Tier II qualified facility criteria:
(1) A Tier I qualified facility meets the qualification criteria in paragraph (g)(2) of this section and has no individual aboveground oil storage container with a capacity greater than 5,000 U.S. gallons.
(2) A Tier II qualified facility is one that has had no single discharge as described in § 112.1(b) exceeding 1,000 U.S. gallons or no two discharges as described in § 112.1(b) each exceeding 42 U.S. gallons within any twelve month period in the three years prior to the SPCC Plan self-certification date, or since becoming subject to this part if the facility has been in operation for less than three years (other than discharges as described in § 112.1(b) that are the result of natural disasters, acts of war, or terrorism), and has an aggregate aboveground oil storage capacity of 10,000 U.S. gallons or less.
§ 112.4 Amendment of Spill Prevention, Control, and Countermeasure Plan by Regional Administrator.
If you are the owner or operator of a facility subject to this part, you must:
(a) Notwithstanding compliance with § 112.3, whenever your facility has discharged more than 1,000 U.S. gallons of oil in a single discharge as described in § 112.1(b), or discharged more than 42 U.S. gallons of oil in each of two discharges as described in § 112.1(b), occurring within any twelve month period, submit the following information to the Regional Administrator within 60 days from the time the facility becomes subject to this section:
(1) Name of the facility;
(2) Your name;
(3) Location of the facility;
(4) Maximum storage or handling capacity of the facility and normal daily throughput;
(5) Corrective action and countermeasures you have taken, including a description of equipment repairs and replacements;
(6) An adequate description of the facility, including maps, flow diagrams, and topographical maps, as necessary;
(7) The cause of such discharge as described in § 112.1(b), including a failure analysis of the system or subsystem in which the failure occurred;
(8) Additional preventive measures you have taken or contemplated to minimize the possibility of recurrence; and
(9) Such other information as the Regional Administrator may reasonably require pertinent to the Plan or discharge.
(b) Take no action under this section until it applies to your facility. This section does not apply until the expiration of the time permitted for the initial preparation and implementation of the Plan under § 112.3, but not including any amendments to the Plan.
(c) Send to the appropriate agency or agencies in charge of oil pollution control activities in the State in which the facility is located a complete copy of all information you provided to the Regional Administrator under paragraph (a) of this section. Upon receipt of the information such State agency or agencies may conduct a review and make recommendations to the Regional Administrator as to further procedures, methods, equipment, and other requirements necessary to prevent and to contain discharges from your facility.
(d) Amend your Plan, if after review by the Regional Administrator of the information you submit under paragraph (a) of this section, or submission of information to EPA by the State agency under paragraph (c) of this section, or after on-site review of your Plan, the Regional Administrator requires that you do so. The Regional Administrator may require you to amend your Plan if he finds that it does not meet the requirements of this part or that amendment is necessary to prevent and contain discharges from your facility.
(e) Act in accordance with this paragraph when the Regional Administrator proposes by certified mail or by personal delivery that you amend your SPCC Plan. If the owner or operator is a corporation, he must also notify by mail the registered agent of such corporation, if any and if known, in the State in which the facility is located. The Regional Administrator must specify the terms of such proposed amendment. Within 30 days from receipt of such notice, you may submit written information, views, and arguments on the proposed amendment. After considering all relevant material presented, the Regional Administrator must either notify you of any amendment required or rescind the notice. You must amend your Plan as required within 30 days after such notice, unless the Regional Administrator, for good cause, specifies another effective date. You must implement the amended Plan as soon as possible, but not later than six months after you amend your Plan, unless the Regional Administrator specifies another date.
(f) If you appeal a decision made by the Regional Administrator requiring an amendment to an SPCC Plan, send the appeal to the EPA Administrator in writing within 30 days of receipt of the notice from the Regional Administrator requiring the amendment under paragraph (e) of this section. You must send a complete copy of the appeal to the Regional Administrator at the time you make the appeal. The appeal must contain a clear and concise statement of the issues and points of fact in the case. It may also contain additional information from you, or from any other person. The EPA Administrator may request additional information from you, or from any other person. The EPA Administrator must render a decision within 60 days of receiving the appeal and must notify you of his decision.
§ 112.5 Amendment of Spill Prevention, Control, and Countermeasure Plan by owners or operators.
If you are the owner or operator of a facility subject to this part, you must:
(a) Amend the SPCC Plan for your facility in accordance with the general requirements in § 112.7, and with any specific section of this part applicable to your facility, when there is a change in the facility design, construction, operation, or maintenance that materially affects its potential for a discharge as described in § 112.1(b). Examples of changes that may require amendment of the Plan include, but are not limited to: commissioning or decommissioning containers; replacement, reconstruction, or movement of containers; reconstruction, replacement, or installation of piping systems; construction or demolition that might alter secondary containment structures; changes of product or service; or revision of standard operation or maintenance procedures at a facility. An amendment made under this section must be prepared within six months, and implemented as soon as possible, but not later than six months following preparation of the amendment.
(b) Notwithstanding compliance with paragraph (a) of this section, complete a review and evaluation of the SPCC Plan at least once every five years from the date your facility becomes subject to this part; or, if your facility was in operation on or before August 16, 2002, five years from the date your last review was required under this part. As a result of this review and evaluation, you must amend your SPCC Plan within six months of the review to include more effective prevention and control technology if the technology has been field-proven at the time of the review and will significantly reduce the likelihood of a discharge as described in § 112.1(b) from the facility. You must implement any amendment as soon as possible, but not later than six months following preparation of any amendment. You must document your completion of the review and evaluation, and must sign a statement as to whether you will amend the Plan, either at the beginning or end of the Plan or in a log or an appendix to the Plan. The following words will suffice, “I have completed review and evaluation of the SPCC Plan for (name of facility) on (date), and will (will not) amend the Plan as a result.”
(c) Except as provided in § 112.6, have a Professional Engineer certify any technical amendments to your Plan in accordance with § 112.3(d).
§ 112.6 Qualified Facilities Plan Requirements.
Qualified facilities meeting the Tier I applicability criteria in § 112.3(g)(1) are subject to the requirements in paragraph (a) of this section. Qualified facilities meeting the Tier II applicability criteria in § 112.3(g)(2) are subject to the requirements in paragraph (b) of this section.
(a) Tier I Qualified Facilities – (1) Preparation and Self-Certification of the Plan. If you are an owner or operator of a facility that meets the Tier I qualified facility criteria in § 112.3(g)(1), you must either: comply with the requirements of paragraph (a)(3) of this section; or prepare and implement a Plan meeting requirements of paragraph (b) of this section; or prepare and implement a Plan meeting the general Plan requirements in § 112.7 and applicable requirements in subparts B and C, including having the Plan certified by a Professional Engineer as required under § 112.3(d). If you do not follow the appendix G template, you must prepare an equivalent Plan that meets all of the applicable requirements listed in this part, and you must supplement it with a section cross-referencing the location of requirements listed in this part and the equivalent requirements in the other prevention plan. To complete the template in appendix G, you must certify that:
(i) You are familiar with the applicable requirements of 40 CFR part 112;
(ii) You have visited and examined the facility;
(iii) You prepared the Plan in accordance with accepted and sound industry practices and standards;
(iv) You have established procedures for required inspections and testing in accordance with industry inspection and testing standards or recommended practices;
(v) You will fully implement the Plan;
(vi) The facility meets the qualification criteria in § 112.3(g)(1);
(vii) The Plan does not deviate from any requirement of this part as allowed by § 112.7(a)(2) and 112.7(d) or include measures pursuant to § 112.9(c)(6) for produced water containers and any associated piping; and
(viii) The Plan and individual(s) responsible for implementing this Plan have the approval of management, and the facility owner or operator has committed the necessary resources to fully implement this Plan.
(2) Technical Amendments. You must certify any technical amendments to your Plan in accordance with paragraph (a)(1) of this section when there is a change in the facility design, construction, operation, or maintenance that affects its potential for a discharge as described in § 112.1(b). If the facility change results in the facility no longer meeting the Tier I qualifying criteria in § 112.3(g)(1) because an individual oil storage container capacity exceeds 5,000 U.S. gallons or the facility capacity exceeds 10,000 U.S. gallons in aggregate aboveground storage capacity, within six months following preparation of the amendment, you must either:
(i) Prepare and implement a Plan in accordance with § 112.6(b) if you meet the Tier II qualified facility criteria in § 112.3(g)(2); or
(ii) Prepare and implement a Plan in accordance with the general Plan requirements in § 112.7, and applicable requirements in subparts B and C, including having the Plan certified by a Professional Engineer as required under § 112.3(d).
(3) Plan Template and Applicable Requirements. Prepare and implement an SPCC Plan that meets the following requirements under § 112.7 and in subparts B and C of this part: introductory paragraph of §§ 112.7, 112.7(a)(3)(i), 112.7(a)(3)(iv), 112.7(a)(3)(vi), 112.7(a)(4), 112.7(a)(5), 112.7(c), 112.7(e), 112.7(f), 112.7(g), 112.7(k), 112.8(b)(1), 112.8(b)(2), 112.8(c)(1), 112.8(c)(3), 112.8(c)(4), 112.8(c)(5), 112.8(c)(6), 112.8(c)(10), 112.8(d)(4), 112.9(b), 112.9(c)(1), 112.9(c)(2), 112.9(c)(3), 112.9(c)(4), 112.9(c)(5), 112.9(d)(1), 112.9(d)(3), 112.9(d)(4), 112.10(b), 112.10(c), 112.10(d), 112.12(b)(1), 112.12(b)(2), 112.12(c)(1), 112.12(c)(3), 112.12(c)(4), 112.12(c)(5), 112.12(c)(6), 112.12(c)(10), and 112.12(d)(4). The template in appendix G to this part has been developed to meet the requirements of 40 CFR part 112 and, when completed and signed by the owner or operator, may be used as the SPCC Plan. Additionally, you must meet the following requirements:
(i) Failure analysis, in lieu of the requirements in § 112.7(b). Where experience indicates a reasonable potential for equipment failure (such as loading or unloading equipment, tank overflow, rupture, or leakage, or any other equipment known to be a source of discharge), include in your Plan a prediction of the direction and total quantity of oil which could be discharged from the facility as a result of each type of major equipment failure.
(ii) Bulk storage container secondary containment, in lieu of the requirements in §§ 112.8(c)(2) and (c)(11) and 112.12(c)(2) and (c)(11). Construct all bulk storage container installations (except mobile refuelers and other non-transportation-related tank trucks), including mobile or portable oil storage containers, so that you provide a secondary means of containment for the entire capacity of the largest single container plus additional capacity to contain precipitation. Dikes, containment curbs, and pits are commonly employed for this purpose. You may also use an alternative system consisting of a drainage trench enclosure that must be arranged so that any discharge will terminate and be safely confined in a catchment basin or holding pond. Position or locate mobile or portable oil storage containers to prevent a discharge as described in § 112.1(b).
(iii) Overfill prevention, in lieu of the requirements in §§ 112.8(c)(8) and 112.12(c)(8). Ensure that each container is provided with a system or documented procedure to prevent overfills of the container, describe the system or procedure in the SPCC Plan and regularly test to ensure proper operation or efficacy.
(b) Tier II Qualified Facilities – (1) Preparation and Self-Certification of Plan. If you are the owner or operator of a facility that meets the Tier II qualified facility criteria in § 112.3(g)(2), you may choose to self-certify your Plan. You must certify in the Plan that:
(i) You are familiar with the requirements of this part;
(ii) You have visited and examined the facility;
(iii) The Plan has been prepared in accordance with accepted and sound industry practices and standards, and with the requirements of this part;
(iv) Procedures for required inspections and testing have been established;
(v) You will fully implement the Plan;
(vi) The facility meets the qualification criteria set forth under § 112.3(g)(2);
(vii) The Plan does not deviate from any requirement of this part as allowed by § 112.7(a)(2) and 112.7(d) or include measures pursuant to § 112.9(c)(6) for produced water containers and any associated piping, except as provided in paragraph (b)(3) of this section; and
(viii) The Plan and individual(s) responsible for implementing the Plan have the full approval of management and the facility owner or operator has committed the necessary resources to fully implement the Plan.
(2) Technical Amendments. If you self-certify your Plan pursuant to paragraph (b)(1) of this section, you must certify any technical amendments to your Plan in accordance with paragraph (b)(1) of this section when there is a change in the facility design, construction, operation, or maintenance that affects its potential for a discharge as described in § 112.1(b), except:
(i) If a Professional Engineer certified a portion of your Plan in accordance with paragraph (b)(4) of this section, and the technical amendment affects this portion of the Plan, you must have the amended provisions of your Plan certified by a Professional Engineer in accordance with paragraph (b)(4)(ii) of this section.
(ii) If the change is such that the facility no longer meets the Tier II qualifying criteria in § 112.3(g)(2) because it exceeds 10,000 U.S. gallons in aggregate aboveground storage capacity you must, within six months following the change, prepare and implement a Plan in accordance with the general Plan requirements in § 112.7 and the applicable requirements in subparts B and C of this part, including having the Plan certified by a Professional Engineer as required under § 112.3(d).
(3) Applicable Requirements. Except as provided in this paragraph, your self-certified SPCC Plan must comply with § 112.7 and the applicable requirements in subparts B and C of this part:
(i) Environmental Equivalence. Your Plan may not include alternate methods which provide environmental equivalence pursuant to § 112.7(a)(2), unless each alternate method has been reviewed and certified in writing by a Professional Engineer, as provided in paragraph (b)(4) of this section.
(ii) Impracticability. Your Plan may not include any determinations that secondary containment is impracticable and provisions in lieu of secondary containment pursuant to § 112.7(d), unless each such determination and alternate measure has been reviewed and certified in writing by a Professional Engineer, as provided in paragraph (b)(4) of this section.
(iii) Produced Water Containers. Your Plan may not include any alternative procedures for skimming produced water containers in lieu of sized secondary containment pursuant to § 112.9(c)(6), unless they have been reviewed and certified in writing by a Professional Engineer, as provided in paragraph (b)(4) of this section.
(4) Professional Engineer Certification of Portions of a Qualified Facility’s Self-Certified Plan.
(i) As described in paragraph (b)(3) of this section, the facility owner or operator may not self-certify alternative measures allowed under § 112.7(a)(2) or (d), that are included in the facility’s Plan. Such measures must be reviewed and certified, in writing, by a licensed Professional Engineer. For each alternative measure allowed under § 112.7(a)(2), the Plan must be accompanied by a written statement by a Professional Engineer that states the reason for nonconformance and describes the alternative method and how it provides equivalent environmental protection in accordance with § 112.7(a)(2). For each determination of impracticability of secondary containment pursuant to § 112.7(d), the Plan must clearly explain why secondary containment measures are not practicable at this facility and provide the alternative measures required in § 112.7(d) in lieu of secondary containment. By certifying each measure allowed under § 112.7(a)(2) and (d), the Professional Engineer attests:
(A) That he is familiar with the requirements of this part;
(B) That he or his agent has visited and examined the facility; and
(C) That the alternative method of environmental equivalence in accordance with § 112.7(a)(2) or the determination of impracticability and alternative measures in accordance with § 112.7(d) is consistent with good engineering practice, including consideration of applicable industry standards, and with the requirements of this part.
(ii) As described in paragraph (b)(3) of this section, the facility owner or operator may not self-certify measures as described in § 112.9(c)(6) for produced water containers and any associated piping. Such measures must be reviewed and certified, in writing, by a licensed Professional Engineer, in accordance with § 112.3(d)(1)(vi).
(iii) The review and certification by the Professional Engineer under this paragraph is limited to the alternative method which achieves equivalent environmental protection pursuant to § 112.7(a)(2); to the impracticability determination and measures in lieu of secondary containment pursuant to § 112.7(d); or the measures pursuant to § 112.9(c)(6) for produced water containers and any associated piping and appurtenances downstream from the container.
§ 112.7 General requirements for Spill Prevention, Control, and Countermeasure Plans.
If you are the owner or operator of a facility subject to this part you must prepare a Plan in accordance with good engineering practices. The Plan must have the full approval of management at a level of authority to commit the necessary resources to fully implement the Plan. You must prepare the Plan in writing. If you do not follow the sequence specified in this section for the Plan, you must prepare an equivalent Plan acceptable to the Regional Administrator that meets all of the applicable requirements listed in this part, and you must supplement it with a section cross-referencing the location of requirements listed in this part and the equivalent requirements in the other prevention plan. If the Plan calls for additional facilities or procedures, methods, or equipment not yet fully operational, you must discuss these items in separate paragraphs, and must explain separately the details of installation and operational start-up. As detailed elsewhere in this section, you must also:
(a)(1) Include a discussion of your facility’s conformance with the requirements listed in this part.
(2) Comply with all applicable requirements listed in this part. Except as provided in § 112.6, your Plan may deviate from the requirements in paragraphs (g), (h)(2) and (3), and (i) of this section and the requirements in subparts B and C of this part, except the secondary containment requirements in paragraphs (c) and (h)(1) of this section, and §§ 112.8(c)(2), 112.8(c)(11), 112.9(c)(2), 112.9(d)(3), 112.10(c), 112.12(c)(2), and 112.12(c)(11), where applicable to a specific facility, if you provide equivalent environmental protection by some other means of spill prevention, control, or countermeasure. Where your Plan does not conform to the applicable requirements in paragraphs (g), (h)(2) and (3), and (i) of this section, or the requirements of subparts B and C of this part, except the secondary containment requirements in paragraph (c) and (h)(1) of this section, and §§ 112.8(c)(2), 112.8(c)(11), 112.9(c)(2), 112.10(c), 112.12(c)(2), and 112.12(c)(11), you must state the reasons for nonconformance in your Plan and describe in detail alternate methods and how you will achieve equivalent environmental protection. If the Regional Administrator determines that the measures described in your Plan do not provide equivalent environmental protection, he may require that you amend your Plan, following the procedures in § 112.4(d) and (e).
(3) Describe in your Plan the physical layout of the facility and include a facility diagram, which must mark the location and contents of each fixed oil storage container and the storage area where mobile or portable containers are located. The facility diagram must identify the location of and mark as “exempt” underground tanks that are otherwise exempted from the requirements of this part under § 112.1(d)(4). The facility diagram must also include all transfer stations and connecting pipes, including intra-facility gathering lines that are otherwise exempted from the requirements of this part under § 112.1(d)(11). You must also address in your Plan:
(i) The type of oil in each fixed container and its storage capacity. For mobile or portable containers, either provide the type of oil and storage capacity for each container or provide an estimate of the potential number of mobile or portable containers, the types of oil, and anticipated storage capacities;
(ii) Discharge prevention measures including procedures for routine handling of products (loading, unloading, and facility transfers, etc.);
(iii) Discharge or drainage controls such as secondary containment around containers and other structures, equipment, and procedures for the control of a discharge;
(iv) Countermeasures for discharge discovery, response, and cleanup (both the facility’s capability and those that might be required of a contractor);
(v) Methods of disposal of recovered materials in accordance with applicable legal requirements; and
(vi) Contact list and phone numbers for the facility response coordinator, National Response Center, cleanup contractors with whom you have an agreement for response, and all appropriate Federal, State, and local agencies who must be contacted in case of a discharge as described in § 112.1(b).
(4) Unless you have submitted a response plan under § 112.20, provide information and procedures in your Plan to enable a person reporting a discharge as described in § 112.1(b) to relate information on the exact address or location and phone number of the facility; the date and time of the discharge, the type of material discharged; estimates of the total quantity discharged; estimates of the quantity discharged as described in § 112.1(b); the source of the discharge; a description of all affected media; the cause of the discharge; any damages or injuries caused by the discharge; actions being used to stop, remove, and mitigate the effects of the discharge; whether an evacuation may be needed; and, the names of individuals and/or organizations who have also been contacted.
(5) Unless you have submitted a response plan under § 112.20, organize portions of the Plan describing procedures you will use when a discharge occurs in a way that will make them readily usable in an emergency, and include appropriate supporting material as appendices.
(b) Where experience indicates a reasonable potential for equipment failure (such as loading or unloading equipment, tank overflow, rupture, or leakage, or any other equipment known to be a source of a discharge), include in your Plan a prediction of the direction, rate of flow, and total quantity of oil which could be discharged from the facility as a result of each type of major equipment failure.
(c) Provide appropriate containment and/or diversionary structures or equipment to prevent a discharge as described in § 112.1(b), except as provided in paragraph (k) of this section for qualified oil-filled operational equipment, and except as provided in § 112.9(d)(3) for flowlines and intra-facility gathering lines at an oil production facility. The entire containment system, including walls and floor, must be capable of containing oil and must be constructed so that any discharge from a primary containment system, such as a tank, will not escape the containment system before cleanup occurs. In determining the method, design, and capacity for secondary containment, you need only to address the typical failure mode, and the most likely quantity of oil that would be discharged. Secondary containment may be either active or passive in design. At a minimum, you must use one of the following prevention systems or its equivalent:
(1) For onshore facilities:
(i) Dikes, berms, or retaining walls sufficiently impervious to contain oil;
(ii) Curbing or drip pans;
(iii) Sumps and collection systems;
(iv) Culverting, gutters, or other drainage systems;
(v) Weirs, booms, or other barriers;
(vi) Spill diversion ponds;
(vii) Retention ponds; or
(viii) Sorbent materials.
(2) For offshore facilities:
(i) Curbing or drip pans; or
(ii) Sumps and collection systems.
(d) Provided your Plan is certified by a licensed Professional Engineer under § 112.3(d), or, in the case of a qualified facility that meets the criteria in § 112.3(g), the relevant sections of your Plan are certified by a licensed Professional Engineer under § 112.6(d), if you determine that the installation of any of the structures or pieces of equipment listed in paragraphs (c) and (h)(1) of this section, and §§ 112.8(c)(2), 112.8(c)(11), 112.9(c)(2), 112.10(c), 112.12(c)(2), and 112.12(c)(11) to prevent a discharge as described in § 112.1(b) from any onshore or offshore facility is not practicable, you must clearly explain in your Plan why such measures are not practicable; for bulk storage containers, conduct both periodic integrity testing of the containers and periodic integrity and leak testing of the valves and piping; and, unless you have submitted a response plan under § 112.20, provide in your Plan the following:
(1) An oil spill contingency plan following the provisions of part 109 of this chapter.
(2) A written commitment of manpower, equipment, and materials required to expeditiously control and remove any quantity of oil discharged that may be harmful.
(e) Inspections, tests, and records. Conduct inspections and tests required by this part in accordance with written procedures that you or the certifying engineer develop for the facility. You must keep these written procedures and a record of the inspections and tests, signed by the appropriate supervisor or inspector, with the SPCC Plan for a period of three years. Records of inspections and tests kept under usual and customary business practices will suffice for purposes of this paragraph.
(f) Personnel, training, and discharge prevention procedures. (1) At a minimum, train your oil-handling personnel in the operation and maintenance of equipment to prevent discharges; discharge procedure protocols; applicable pollution control laws, rules, and regulations; general facility operations; and, the contents of the facility SPCC Plan.
(2) Designate a person at each applicable facility who is accountable for discharge prevention and who reports to facility management.
(3) Schedule and conduct discharge prevention briefings for your oil-handling personnel at least once a year to assure adequate understanding of the SPCC Plan for that facility. Such briefings must highlight and describe known discharges as described in § 112.1(b) or failures, malfunctioning components, and any recently developed precautionary measures.
(g) Security (excluding oil production facilities). Describe in your Plan how you secure and control access to the oil handling, processing and storage areas; secure master flow and drain valves; prevent unauthorized access to starter controls on oil pumps; secure out-of-service and loading/unloading connections of oil pipelines; and address the appropriateness of security lighting to both prevent acts of vandalism and assist in the discovery of oil discharges.
(h) Facility tank car and tank truck loading/unloading rack (excluding offshore facilities).
(1) Where loading/unloading rack drainage does not flow into a catchment basin or treatment facility designed to handle discharges, use a quick drainage system for tank car or tank truck loading/unloading racks. You must design any containment system to hold at least the maximum capacity of any single compartment of a tank car or tank truck loaded or unloaded at the facility.
(2) Provide an interlocked warning light or physical barrier system, warning signs, wheel chocks or vehicle brake interlock system in the area adjacent to a loading/unloading rack, to prevent vehicles from departing before complete disconnection of flexible or fixed oil transfer lines.
(3) Prior to filling and departure of any tank car or tank truck, closely inspect for discharges the lowermost drain and all outlets of such vehicles, and if necessary, ensure that they are tightened, adjusted, or replaced to prevent liquid discharge while in transit.
(i) If a field-constructed aboveground container undergoes a repair, alteration, reconstruction, or a change in service that might affect the risk of a discharge or failure due to brittle fracture or other catastrophe, or has discharged oil or failed due to brittle fracture failure or other catastrophe, evaluate the container for risk of discharge or failure due to brittle fracture or other catastrophe, and as necessary, take appropriate action.
(j) In addition to the minimal prevention standards listed under this section, include in your Plan a complete discussion of conformance with the applicable requirements and other effective discharge prevention and containment procedures listed in this part or any applicable more stringent State rules, regulations, and guidelines.
(k) Qualified Oil-filled Operational Equipment. The owner or operator of a facility with oil-filled operational equipment that meets the qualification criteria in paragraph (k)(1) of this sub-section may choose to implement for this qualified oil-filled operational equipment the alternate requirements as described in paragraph (k)(2) of this sub-section in lieu of general secondary containment required in paragraph (c) of this section.
(1) Qualification Criteria – Reportable Discharge History: The owner or operator of a facility that has had no single discharge as described in § 112.1(b) from any oil-filled operational equipment exceeding 1,000 U.S. gallons or no two discharges as described in § 112.1(b) from any oil-filled operational equipment each exceeding 42 U.S. gallons within any twelve month period in the three years prior to the SPCC Plan certification date, or since becoming subject to this part if the facility has been in operation for less than three years (other than oil discharges as described in § 112.1(b) that are the result of natural disasters, acts of war or terrorism); and
(2) Alternative Requirements to General Secondary Containment. If secondary containment is not provided for qualified oil-filled operational equipment pursuant to paragraph (c) of this section, the owner or operator of a facility with qualified oil-filled operational equipment must:
(i) Establish and document the facility procedures for inspections or a monitoring program to detect equipment failure and/or a discharge; and
(ii) Unless you have submitted a response plan under § 112.20, provide in your Plan the following:
(A) An oil spill contingency plan following the provisions of part 109 of this chapter.
(B) A written commitment of manpower, equipment, and materials required to expeditiously control and remove any quantity of oil discharged that may be harmful.
Subpart B – Requirements for Petroleum Oils and Non-Petroleum Oils, Except Animal Fats and Oils and Greases, and Fish and Marine Mammal Oils; and Vegetable Oils (Including Oils from Seeds, Nuts, Fruits, and Kernels)
§ 112.8 Spill Prevention, Control, and Countermeasure Plan requirements for onshore facilities (excluding production facilities).
If you are the owner or operator of an onshore facility (excluding a production facility), you must:
(a) Meet the general requirements for the Plan listed under § 112.7, and the specific discharge prevention and containment procedures listed in this section.
(b) Facility drainage. (1) Restrain drainage from diked storage areas by valves to prevent a discharge into the drainage system or facility effluent treatment system, except where facility systems are designed to control such discharge. You may empty diked areas by pumps or ejectors; however, you must manually activate these pumps or ejectors and must inspect the condition of the accumulation before starting, to ensure no oil will be discharged.
(2) Use valves of manual, open-and-closed design, for the drainage of diked areas. You may not use flapper-type drain valves to drain diked areas. If your facility drainage drains directly into a watercourse and not into an on-site wastewater treatment plant, you must inspect and may drain uncontaminated retained stormwater, as provided in paragraphs (c)(3)(ii), (iii), and (iv) of this section.
(3) Design facility drainage systems from undiked areas with a potential for a discharge (such as where piping is located outside containment walls or where tank truck discharges may occur outside the loading area) to flow into ponds, lagoons, or catchment basins designed to retain oil or return it to the facility. You must not locate catchment basins in areas subject to periodic flooding.
(4) If facility drainage is not engineered as in paragraph (b)(3) of this section, equip the final discharge of all ditches inside the facility with a diversion system that would, in the event of an uncontrolled discharge, retain oil in the facility.
(5) Where drainage waters are treated in more than one treatment unit and such treatment is continuous, and pump transfer is needed, provide two “lift” pumps and permanently install at least one of the pumps. Whatever techniques you use, you must engineer facility drainage systems to prevent a discharge as described in § 112.1(b) in case there is an equipment failure or human error at the facility.
(c) Bulk storage containers. (1) Not use a container for the storage of oil unless its material and construction are compatible with the material stored and conditions of storage such as pressure and temperature.
(2) Construct all bulk storage tank installations (except mobile refuelers and other non-transportation-related tank trucks) so that you provide a secondary means of containment for the entire capacity of the largest single container and sufficient freeboard to contain precipitation. You must ensure that diked areas are sufficiently impervious to contain discharged oil. Dikes, containment curbs, and pits are commonly employed for this purpose. You may also use an alternative system consisting of a drainage trench enclosure that must be arranged so that any discharge will terminate and be safely confined in a facility catchment basin or holding pond.
(3) Not allow drainage of uncontaminated rainwater from the diked area into a storm drain or discharge of an effluent into an open watercourse, lake, or pond, bypassing the facility treatment system unless you:
(i) Normally keep the bypass valve sealed closed.
(ii) Inspect the retained rainwater to ensure that its presence will not cause a discharge as described in § 112.1(b).
(iii) Open the bypass valve and reseal it following drainage under responsible supervision; and
(iv) Keep adequate records of such events, for example, any records required under permits issued in accordance with §§ 122.41(j)(2) and 122.41(m)(3) of this chapter.
(4) Protect any completely buried metallic storage tank installed on or after January 10, 1974 from corrosion by coatings or cathodic protection compatible with local soil conditions. You must regularly leak test such completely buried metallic storage tanks.
(5) Not use partially buried or bunkered metallic tanks for the storage of oil, unless you protect the buried section of the tank from corrosion. You must protect partially buried and bunkered tanks from corrosion by coatings or cathodic protection compatible with local soil conditions.
(6) Test or inspect each aboveground container for integrity on a regular schedule and whenever you make material repairs. You must determine, in accordance with industry standards, the appropriate qualifications for personnel performing tests and inspections, the frequency and type of testing and inspections, which take into account container size, configuration, and design (such as containers that are: shop-built, field-erected, skid-mounted, elevated, equipped with a liner, double-walled, or partially buried). Examples of these integrity tests include, but are not limited to: visual inspection, hydrostatic testing, radiographic testing, ultrasonic testing, acoustic emissions testing, or other systems of non-destructive testing. You must keep comparison records and you must also inspect the container’s supports and foundations. In addition, you must frequently inspect the outside of the container for signs of deterioration, discharges, or accumulation of oil inside diked areas. Records of inspections and tests kept under usual and customary business practices satisfy the recordkeeping requirements of this paragraph.
(7) Control leakage through defective internal heating coils by monitoring the steam return and exhaust lines for contamination from internal heating coils that discharge into an open watercourse, or pass the steam return or exhaust lines through a settling tank, skimmer, or other separation or retention system.
(8) Engineer or update each container installation in accordance with good engineering practice to avoid discharges. You must provide at least one of the following devices:
(i) High liquid level alarms with an audible or visual signal at a constantly attended operation or surveillance station. In smaller facilities an audible air vent may suffice.
(ii) High liquid level pump cutoff devices set to stop flow at a predetermined container content level.
(iii) Direct audible or code signal communication between the container gauger and the pumping station.
(iv) A fast response system for determining the liquid level of each bulk storage container such as digital computers, telepulse, or direct vision gauges. If you use this alternative, a person must be present to monitor gauges and the overall filling of bulk storage containers.
(v) You must regularly test liquid level sensing devices to ensure proper operation.
(9) Observe effluent treatment facilities frequently enough to detect possible system upsets that could cause a discharge as described in § 112.1(b).
(10) Promptly correct visible discharges which result in a loss of oil from the container, including but not limited to seams, gaskets, piping, pumps, valves, rivets, and bolts. You must promptly remove any accumulations of oil in diked areas.
(11) Position or locate mobile or portable oil storage containers to prevent a discharge as described in § 112.1(b). Except for mobile refuelers and other non-transportation-related tank trucks, you must furnish a secondary means of containment, such as a dike or catchment basin, sufficient to contain the capacity of the largest single compartment or container with sufficient freeboard to contain precipitation.
(d) Facility transfer operations, pumping, and facility process. (1) Provide buried piping that is installed or replaced on or after August 16, 2002, with a protective wrapping and coating. You must also cathodically protect such buried piping installations or otherwise satisfy the corrosion protection standards for piping in part 280 of this chapter or a State program approved under part 281 of this chapter. If a section of buried line is exposed for any reason, you must carefully inspect it for deterioration. If you find corrosion damage, you must undertake additional examination and corrective action as indicated by the magnitude of the damage.
(2) Cap or blank-flange the terminal connection at the transfer point and mark it as to origin when piping is not in service or is in standby service for an extended time.
(3) Properly design pipe supports to minimize abrasion and corrosion and allow for expansion and contraction.
(4) Regularly inspect all aboveground valves, piping, and appurtenances. During the inspection you must assess the general condition of items, such as flange joints, expansion joints, valve glands and bodies, catch pans, pipeline supports, locking of valves, and metal surfaces. You must also conduct integrity and leak testing of buried piping at the time of installation, modification, construction, relocation, or replacement.
(5) Warn all vehicles entering the facility to be sure that no vehicle will endanger aboveground piping or other oil transfer operations.
§ 112.9 Spill Prevention, Control, and Countermeasure Plan Requirements for onshore oil production facilities (excluding drilling and workover facilities).
If you are the owner or operator of an onshore oil production facility (excluding a drilling or workover facility), you must:
(a) Meet the general requirements for the Plan listed under § 112.7, and the specific discharge prevention and containment procedures listed under this section.
(b) Oil production facility drainage. (1) At tank batteries and separation and treating areas where there is a reasonable possibility of a discharge as described in § 112.1(b), close and seal at all times drains of dikes or drains of equivalent measures required under § 112.7(c)(1), except when draining uncontaminated rainwater. Prior to drainage, you must inspect the diked area and take action as provided in § 112.8(c)(3)(ii), (iii), and (iv). You must remove accumulated oil on the rainwater and return it to storage or dispose of it in accordance with legally approved methods.
(2) Inspect at regularly scheduled intervals field drainage systems (such as drainage ditches or road ditches), and oil traps, sumps, or skimmers, for an accumulation of oil that may have resulted from any small discharge. You must promptly remove any accumulations of oil.
(c) Oil production facility bulk storage containers. (1) Not use a container for the storage of oil unless its material and construction are compatible with the material stored and the conditions of storage.
(2) Except as described in paragraph (c)(5) of this section for flow-through process vessels and paragraph (c)(6) of this section for produced water containers and any associated piping and appurtenances downstream from the container, construct all tank battery, separation, and treating facility installations, so that you provide a secondary means of containment for the entire capacity of the largest single container and sufficient freeboard to contain precipitation. You must safely confine drainage from undiked areas in a catchment basin or holding pond.
(3) Except as described in paragraph (c)(5) of this section for flow-through process vessels and paragraph (c)(6) of this section for produced water containers and any associated piping and appurtenances downstream from the container, periodically and upon a regular schedule visually inspect each container of oil for deterioration and maintenance needs, including the foundation and support of each container that is on or above the surface of the ground.
(4) Engineer or update new and old tank battery installations in accordance with good engineering practice to prevent discharges. You must provide at least one of the following:
(i) Container capacity adequate to assure that a container will not overfill if a pumper/gauger is delayed in making regularly scheduled rounds.
(ii) Overflow equalizing lines between containers so that a full container can overflow to an adjacent container.
(iii) Vacuum protection adequate to prevent container collapse during a pipeline run or other transfer of oil from the container.
(iv) High level sensors to generate and transmit an alarm signal to the computer where the facility is subject to a computer production control system.
(5) Flow-through process vessels. The owner or operator of a facility with flow-through process vessels may choose to implement the alternate requirements as described below in lieu of sized secondary containment required in paragraphs (c)(2) and (c)(3) of this section.
(i) Periodically and on a regular schedule visually inspect and/or test flow-through process vessels and associated components (such as dump valves) for leaks, corrosion, or other conditions that could lead to a discharge as described in § 112.1(b).
(ii) Take corrective action or make repairs to flow-through process vessels and any associated components as indicated by regularly scheduled visual inspections, tests, or evidence of an oil discharge.
(iii) Promptly remove or initiate actions to stabilize and remediate any accumulations of oil discharges associated with flow-through process vessels.
(iv) If your facility discharges more than 1,000 U.S. gallons of oil in a single discharge as described in § 112.1(b), or discharges more than 42 U.S. gallons of oil in each of two discharges as described in § 112.1(b) within any twelve month period, from flow-through process vessels (excluding discharges that are the result of natural disasters, acts of war, or terrorism) then you must, within six months from the time the facility becomes subject to this paragraph, ensure that all flow-through process vessels subject to this subpart comply with § 112.9(c)(2) and (c)(3).
(6) Produced water containers. For each produced water container, comply with § 112.9(c)(1) and (c)(4); and § 112.9(c)(2) and (c)(3), or comply with the provisions of the following paragraphs (c)(6)(i) through (v):
(i) Implement, on a regular schedule, a procedure for each produced water container that is designed to separate the free-phase oil that accumulates on the surface of the produced water. Include in the Plan a description of the procedures, frequency, amount of free-phase oil expected to be maintained inside the container, and a Professional Engineer certification in accordance with § 112.3(d)(1)(vi). Maintain records of such events in accordance with § 112.7(e). Records kept under usual and customary business practices will suffice for purposes of this paragraph. If this procedure is not implemented as described in the Plan or no records are maintained, then you must comply with § 112.9(c)(2) and (c)(3).
(ii) On a regular schedule, visually inspect and/or test the produced water container and associated piping for leaks, corrosion, or other conditions that could lead to a discharge as described in § 112.1(b) in accordance with good engineering practice.
(iii) Take corrective action or make repairs to the produced water container and any associated piping as indicated by regularly scheduled visual inspections, tests, or evidence of an oil discharge.
(iv) Promptly remove or initiate actions to stabilize and remediate any accumulations of oil discharges associated with the produced water container.
(v) If your facility discharges more than 1,000 U.S. gallons of oil in a single discharge as described in § 112.1(b), or discharges more than 42 U.S. gallons of oil in each of two discharges as described in § 112.1(b) within any twelve month period from a produced water container subject to this subpart (excluding discharges that are the result of natural disasters, acts of war, or terrorism) then you must, within six months from the time the facility becomes subject to this paragraph, ensure that all produced water containers subject to this subpart comply with § 112.9(c)(2) and (c)(3).
(d) Facility transfer operations, oil production facility. (1) Periodically and upon a regular schedule inspect all aboveground valves and piping associated with transfer operations for the general condition of flange joints, valve glands and bodies, drip pans, pipe supports, pumping well polish rod stuffing boxes, bleeder and gauge valves, and other such items.
(2) Inspect saltwater (oil field brine) disposal facilities often, particularly following a sudden change in atmospheric temperature, to detect possible system upsets capable of causing a discharge.
(3) For flowlines and intra-facility gathering lines that are not provided with secondary containment in accordance with § 112.7(c), unless you have submitted a response plan under § 112.20, provide in your Plan the following:
(i) An oil spill contingency plan following the provisions of part 109 of this chapter.
(ii) A written commitment of manpower, equipment, and materials required to expeditiously control and remove any quantity of oil discharged that might be harmful.
(4) Prepare and implement a written program of flowline/intra-facility gathering line maintenance. The maintenance program must address your procedures to:
(i) Ensure that flowlines and intra-facility gathering lines and associated valves and equipment are compatible with the type of production fluids, their potential corrosivity, volume, and pressure, and other conditions expected in the operational environment.
(ii) Visually inspect and/or test flowlines and intra-facility gathering lines and associated appurtenances on a periodic and regular schedule for leaks, oil discharges, corrosion, or other conditions that could lead to a discharge as described in § 112.1(b). For flowlines and intra-facility gathering lines that are not provided with secondary containment in accordance with § 112.7(c), the frequency and type of testing must allow for the implementation of a contingency plan as described under part 109 of this chapter.
(iii) Take corrective action or make repairs to any flowlines and intra-facility gathering lines and associated appurtenances as indicated by regularly scheduled visual inspections, tests, or evidence of a discharge.
(iv) Promptly remove or initiate actions to stabilize and remediate any accumulations of oil discharges associated with flowlines, intra-facility gathering lines, and associated appurtenances.
§ 112.10 Spill Prevention, Control, and Countermeasure Plan requirements for onshore oil drilling and workover facilities.
If you are the owner or operator of an onshore oil drilling and workover facility, you must:
(a) Meet the general requirements listed under § 112.7, and also meet the specific discharge prevention and containment procedures listed under this section.
(b) Position or locate mobile drilling or workover equipment so as to prevent a discharge as described in § 112.1(b).
(c) Provide catchment basins or diversion structures to intercept and contain discharges of fuel, crude oil, or oily drilling fluids.
(d) Install a blowout prevention (BOP) assembly and well control system before drilling below any casing string or during workover operations. The BOP assembly and well control system must be capable of controlling any well-head pressure that may be encountered while that BOP assembly and well control system are on the well.
§ 112.11 Spill Prevention, Control, and Countermeasure Plan requirements for offshore oil drilling, production, or workover facilities.
If you are the owner or operator of an offshore oil drilling, production, or workover facility, you must:
(a) Meet the general requirements listed under § 112.7, and also meet the specific discharge prevention and containment procedures listed under this section.
(b) Use oil drainage collection equipment to prevent and control small oil discharges around pumps, glands, valves, flanges, expansion joints, hoses, drain lines, separators, treaters, tanks, and associated equipment. You must control and direct facility drains toward a central collection sump to prevent the facility from having a discharge as described in § 112.1(b). Where drains and sumps are not practicable, you must remove oil contained in collection equipment as often as necessary to prevent overflow.
(c) For facilities employing a sump system, provide adequately sized sump and drains and make available a spare pump to remove liquid from the sump and assure that oil does not escape. You must employ a regularly scheduled preventive maintenance inspection and testing program to assure reliable operation of the liquid removal system and pump start-up device. Redundant automatic sump pumps and control devices may be required on some installations.
(d) At facilities with areas where separators and treaters are equipped with dump valves which predominantly fail in the closed position and where pollution risk is high, specially equip the facility to prevent the discharge of oil. You must prevent the discharge of oil by:
(1) Extending the flare line to a diked area if the separator is near shore;
(2) Equipping the separator with a high liquid level sensor that will automatically shut in wells producing to the separator; or
(3) Installing parallel redundant dump valves.
(e) Equip atmospheric storage or surge containers with high liquid level sensing devices that activate an alarm or control the flow, or otherwise prevent discharges.
(f) Equip pressure containers with high and low pressure sensing devices that activate an alarm or control the flow.
(g) Equip containers with suitable corrosion protection.
(h) Prepare and maintain at the facility a written procedure within the Plan for inspecting and testing pollution prevention equipment and systems.
(i) Conduct testing and inspection of the pollution prevention equipment and systems at the facility on a scheduled periodic basis, commensurate with the complexity, conditions, and circumstances of the facility and any other appropriate regulations. You must use simulated discharges for testing and inspecting human and equipment pollution control and countermeasure systems.
(j) Describe in detailed records surface and subsurface well shut-in valves and devices in use at the facility for each well sufficiently to determine their method of activation or control, such as pressure differential, change in fluid or flow conditions, combination of pressure and flow, manual or remote control mechanisms.
(k) Install a BOP assembly and well control system during workover operations and before drilling below any casing string. The BOP assembly and well control system must be capable of controlling any well-head pressure that may be encountered while the BOP assembly and well control system are on the well.
(l) Equip all manifolds (headers) with check valves on individual flowlines.
(m) Equip the flowline with a high pressure sensing device and shut-in valve at the wellhead if the shut-in well pressure is greater than the working pressure of the flowline and manifold valves up to and including the header valves. Alternatively you may provide a pressure relief system for flowlines.
(n) Protect all piping appurtenant to the facility from corrosion, such as with protective coatings or cathodic protection.
(o) Adequately protect sub-marine piping appurtenant to the facility against environmental stresses and other activities such as fishing operations.
(p) Maintain sub-marine piping appurtenant to the facility in good operating condition at all times. You must periodically and according to a schedule inspect or test such piping for failures. You must document and keep a record of such inspections or tests at the facility.
Subpart C – Requirements for Animal Fats and Oils and Greases, and Fish and Marine Mammal Oils; and for Vegetable Oils, including Oils from Seeds, Nuts, Fruits, and Kernels
§ 112.12 Spill Prevention, Control, and Countermeasure Plan requirements.
If you are the owner or operator of an onshore facility, you must:
(a) Meet the general requirements for the Plan listed under § 112.7, and the specific discharge prevention and containment procedures listed in this section.
(b) Facility drainage. (1) Restrain drainage from diked storage areas by valves to prevent a discharge into the drainage system or facility effluent treatment system, except where facility systems are designed to control such discharge. You may empty diked areas by pumps or ejectors; however, you must manually activate these pumps or ejectors and must inspect the condition of the accumulation before starting, to ensure no oil will be discharged.
(2) Use valves of manual, open-and-closed design, for the drainage of diked areas. You may not use flapper-type drain valves to drain diked areas. If your facility drainage drains directly into a watercourse and not into an on-site wastewater treatment plant, you must inspect and may drain uncontaminated retained stormwater, subject to the requirements of paragraphs (c)(3)(ii), (iii), and (iv) of this section.
(3) Design facility drainage systems from undiked areas with a potential for a discharge (such as where piping is located outside containment walls or where tank truck discharges may occur outside the loading area) to flow into ponds, lagoons, or catchment basins designed to retain oil or return it to the facility. You must not locate catchment basins in areas subject to periodic flooding.
(4) If facility drainage is not engineered as in paragraph (b)(3) of this section, equip the final discharge of all ditches inside the facility with a diversion system that would, in the event of an uncontrolled discharge, retain oil in the facility.
(5) Where drainage waters are treated in more than one treatment unit and such treatment is continuous, and pump transfer is needed, provide two “lift” pumps and permanently install at least one of the pumps. Whatever techniques you use, you must engineer facility drainage systems to prevent a discharge as described in § 112.1(b) in case there is an equipment failure or human error at the facility.
(c) Bulk storage containers. (1) Not use a container for the storage of oil unless its material and construction are compatible with the material stored and conditions of storage such as pressure and temperature.
(2) Construct all bulk storage tank installations (except mobile refuelers and other non-transportation-related tank trucks) so that you provide a secondary means of containment for the entire capacity of the largest single container and sufficient freeboard to contain precipitation. You must ensure that diked areas are sufficiently impervious to contain discharged oil. Dikes, containment curbs, and pits are commonly employed for this purpose. You may also use an alternative system consisting of a drainage trench enclosure that must be arranged so that any discharge will terminate and be safely confined in a facility catchment basin or holding pond.
(3) Not allow drainage of uncontaminated rainwater from the diked area into a storm drain or discharge of an effluent into an open watercourse, lake, or pond, bypassing the facility treatment system unless you:
(i) Normally keep the bypass valve sealed closed.
(ii) Inspect the retained rainwater to ensure that its presence will not cause a discharge as described in § 112.1(b).
(iii) Open the bypass valve and reseal it following drainage under responsible supervision; and
(iv) Keep adequate records of such events, for example, any records required under permits issued in accordance with §§ 122.41(j)(2) and 122.41(m)(3) of this chapter.
(4) Protect any completely buried metallic storage tank installed on or after January 10, 1974 from corrosion by coatings or cathodic protection compatible with local soil conditions. You must regularly leak test such completely buried metallic storage tanks.
(5) Not use partially buried or bunkered metallic tanks for the storage of oil, unless you protect the buried section of the tank from corrosion. You must protect partially buried and bunkered tanks from corrosion by coatings or cathodic protection compatible with local soil conditions.
(6) Bulk storage container inspections.
(i) Except for containers that meet the criteria provided in paragraph (c)(6)(ii) of this section, test or inspect each aboveground container for integrity on a regular schedule and whenever you make material repairs. You must determine, in accordance with industry standards, the appropriate qualifications for personnel performing tests and inspections, the frequency and type of testing and inspections, which take into account container size, configuration, and design (such as containers that are: shop-built, field-erected, skid-mounted, elevated, equipped with a liner, double-walled, or partially buried). Examples of these integrity tests include, but are not limited to: Visual inspection, hydrostatic testing, radiographic testing, ultrasonic testing, acoustic emissions testing, or other systems of non-destructive testing. You must keep comparison records and you must also inspect the container’s supports and foundations. In addition, you must frequently inspect the outside of the container for signs of deterioration, discharges, or accumulation of oil inside diked areas. Records of inspections and tests kept under usual and customary business practices satisfy the recordkeeping requirements of this paragraph.
(ii) For bulk storage containers that are subject to 21 CFR part 110, are elevated, constructed of austenitic stainless steel, have no external insulation, and are shop-fabricated, conduct formal visual inspection on a regular schedule. In addition, you must frequently inspect the outside of the container for signs of deterioration, discharges, or accumulation of oil inside diked areas. You must determine and document in the Plan the appropriate qualifications for personnel performing tests and inspections. Records of inspections and tests kept under usual and customary business practices satisfy the recordkeeping requirements of this paragraph (c)(6).
(7) Control leakage through defective internal heating coils by monitoring the steam return and exhaust lines for contamination from internal heating coils that discharge into an open watercourse, or pass the steam return or exhaust lines through a settling tank, skimmer, or other separation or retention system.
(8) Engineer or update each container installation in accordance with good engineering practice to avoid discharges. You must provide at least one of the following devices:
(i) High liquid level alarms with an audible or visual signal at a constantly attended operation or surveillance station. In smaller facilities an audible air vent may suffice.
(ii) High liquid level pump cutoff devices set to stop flow at a predetermined container content level.
(iii) Direct audible or code signal communication between the container gauger and the pumping station.
(iv) A fast response system for determining the liquid level of each bulk storage container such as digital computers, telepulse, or direct vision gauges. If you use this alternative, a person must be present to monitor gauges and the overall filling of bulk storage containers.
(v) You must regularly test liquid level sensing devices to ensure proper operation.
(9) Observe effluent treatment facilities frequently enough to detect possible system upsets that could cause a discharge as described in § 112.1(b).
(10) Promptly correct visible discharges which result in a loss of oil from the container, including but not limited to seams, gaskets, piping, pumps, valves, rivets, and bolts. You must promptly remove any accumulations of oil in diked areas.
(11) Position or locate mobile or portable oil storage containers to prevent a discharge as described in § 112.1(b). Except for mobile refuelers and other non-transportation-related tank trucks, you must furnish a secondary means of containment, such as a dike or catchment basin, sufficient to contain the capacity of the largest single compartment or container with sufficient freeboard to contain precipitation.
(d) Facility transfer operations, pumping, and facility process. (1) Provide buried piping that is installed or replaced on or after August 16, 2002, with a protective wrapping and coating. You must also cathodically protect such buried piping installations or otherwise satisfy the corrosion protection standards for piping in part 280 of this chapter or a State program approved under part 281 of this chapter. If a section of buried line is exposed for any reason, you must carefully inspect it for deterioration. If you find corrosion damage, you must undertake additional examination and corrective action as indicated by the magnitude of the damage.
(2) Cap or blank-flange the terminal connection at the transfer point and mark it as to origin when piping is not in service or is in standby service for an extended time.
(3) Properly design pipe supports to minimize abrasion and corrosion and allow for expansion and contraction.
(4) Regularly inspect all aboveground valves, piping, and appurtenances. During the inspection you must assess the general condition of items, such as flange joints, expansion joints, valve glands and bodies, catch pans, pipeline supports, locking of valves, and metal surfaces. You must also conduct integrity and leak testing of buried piping at the time of installation, modification, construction, relocation, or replacement.
(5) Warn all vehicles entering the facility to be sure that no vehicle will endanger aboveground piping or other oil transfer operations.
§§ 112.13-112.15 [Reserved]
Subpart D – Response Requirements
§ 112.20 Facility response plans.
(a) The owner or operator of any non-transportation-related onshore facility that, because of its location, could reasonably be expected to cause substantial harm to the environment by discharging oil into or on the navigable waters or adjoining shorelines shall prepare and submit a facility response plan to the Regional Administrator, according to the following provisions:
(1) For the owner or operator of a facility in operation on or before February 18, 1993 who is required to prepare and submit a response plan under 33 U.S.C. 1321(j)(5), the Oil Pollution Act of 1990 (Pub. L. 101-380, 33 U.S.C. 2701 et seq.) requires the submission of a response plan that satisfies the requirements of 33 U.S.C. 1321(j)(5) no later than February 18, 1993.
(i) The owner or operator of an existing facility that was in operation on or before February 18, 1993 who submitted a response plan by February 18, 1993 shall revise the response plan to satisfy the requirements of this section and resubmit the response plan or updated portions of the response plan to the Regional Administrator by February 18, 1995.
(ii) The owner or operator of an existing facility in operation on or before February 18, 1993 who failed to submit a response plan by February 18, 1993 shall prepare and submit a response plan that satisfies the requirements of this section to the Regional Administrator before August 30, 1994.
(2) The owner or operator of a facility in operation on or after August 30, 1994 that satisfies the criteria in paragraph (f)(1) of this section or that is notified by the Regional Administrator pursuant to paragraph (b) of this section shall prepare and submit a facility response plan that satisfies the requirements of this section to the Regional Administrator.
(i) For a facility that commenced operations after February 18, 1993 but prior to August 30, 1994, and is required to prepare and submit a response plan based on the criteria in paragraph (f)(1) of this section, the owner or operator shall submit the response plan or updated portions of the response plan, along with a completed version of the response plan cover sheet contained in appendix F to this part, to the Regional Administrator prior to August 30, 1994.
(ii) For a newly constructed facility that commences operation after August 30, 1994, and is required to prepare and submit a response plan based on the criteria in paragraph (f)(1) of this section, the owner or operator shall submit the response plan, along with a completed version of the response plan cover sheet contained in appendix F to this part, to the Regional Administrator prior to the start of operations (adjustments to the response plan to reflect changes that occur at the facility during the start-up phase of operations must be submitted to the Regional Administrator after an operational trial period of 60 days).
(iii) For a facility required to prepare and submit a response plan after August 30, 1994, as a result of a planned change in design, construction, operation, or maintenance that renders the facility subject to the criteria in paragraph (f)(1) of this section, the owner or operator shall submit the response plan, along with a completed version of the response plan cover sheet contained in appendix F to this part, to the Regional Administrator before the portion of the facility undergoing change commences operations (adjustments to the response plan to reflect changes that occur at the facility during the start-up phase of operations must be submitted to the Regional Administrator after an operational trial period of 60 days).
(iv) For a facility required to prepare and submit a response plan after August 30, 1994, as a result of an unplanned event or change in facility characteristics that renders the facility subject to the criteria in paragraph (f)(1) of this section, the owner or operator shall submit the response plan, along with a completed version of the response plan cover sheet contained in appendix F to this part, to the Regional Administrator within six months of the unplanned event or change.
(3) In the event the owner or operator of a facility that is required to prepare and submit a response plan uses an alternative formula that is comparable to one contained in appendix C to this part to evaluate the criterion in paragraph (f)(1)(ii)(B) or (f)(1)(ii)(C) of this section, the owner or operator shall attach documentation to the response plan cover sheet contained in appendix F to this part that demonstrates the reliability and analytical soundness of the alternative formula.
(4) Preparation and submission of response plans – Animal fat and vegetable oil facilities. The owner or operator of any non-transportation-related facility that handles, stores, or transports animal fats and vegetable oils must prepare and submit a facility response plan as follows:
(i) Facilities with approved plans. The owner or operator of a facility with a facility response plan that has been approved under paragraph (c) of this section by July 31, 2000 need not prepare or submit a revised plan except as otherwise required by paragraphs (b), (c), or (d) of this section.
(ii) Facilities with plans that have been submitted to the Regional Administrator. Except for facilities with approved plans as provided in paragraph (a)(4)(i) of this section, the owner or operator of a facility that has submitted a response plan to the Regional Administrator prior to July 31, 2000 must review the plan to determine if it meets or exceeds the applicable provisions of this part. An owner or operator need not prepare or submit a new plan if the existing plan meets or exceeds the applicable provisions of this part. If the plan does not meet or exceed the applicable provisions of this part, the owner or operator must prepare and submit a new plan by September 28, 2000.
(iii) Newly regulated facilities. The owner or operator of a newly constructed facility that commences operation after July 31, 2000 must prepare and submit a plan to the Regional Administrator in accordance with paragraph (a)(2)(ii) of this section. The plan must meet or exceed the applicable provisions of this part. The owner or operator of an existing facility that must prepare and submit a plan after July 31, 2000 as a result of a planned or unplanned change in facility characteristics that causes the facility to become regulated under paragraph (f)(1) of this section, must prepare and submit a plan to the Regional Administrator in accordance with paragraph (a)(2)(iii) or (iv) of this section, as appropriate. The plan must meet or exceed the applicable provisions of this part.
(iv) Facilities amending existing plans. The owner or operator of a facility submitting an amended plan in accordance with paragraph (d) of this section after July 31, 2000, including plans that had been previously approved, must also review the plan to determine if it meets or exceeds the applicable provisions of this part. If the plan does not meet or exceed the applicable provisions of this part, the owner or operator must revise and resubmit revised portions of an amended plan to the Regional Administrator in accordance with paragraph (d) of this section, as appropriate. The plan must meet or exceed the applicable provisions of this part.
(b)(1) The Regional Administrator may at any time require the owner or operator of any non-transportation-related onshore facility to prepare and submit a facility response plan under this section after considering the factors in paragraph (f)(2) of this section. If such a determination is made, the Regional Administrator shall notify the facility owner or operator in writing and shall provide a basis for the determination. If the Regional Administrator notifies the owner or operator in writing of the requirement to prepare and submit a response plan under this section, the owner or operator of the facility shall submit the response plan to the Regional Administrator within six months of receipt of such written notification.
(2) The Regional Administrator shall review plans submitted by such facilities to determine whether the facility could, because of its location, reasonably be expected to cause significant and substantial harm to the environment by discharging oil into or on the navigable waters or adjoining shorelines.
(c) The Regional Administrator shall determine whether a facility could, because of its location, reasonably be expected to cause significant and substantial harm to the environment by discharging oil into or on the navigable waters or adjoining shorelines, based on the factors in paragraph (f)(3) of this section. If such a determination is made, the Regional Administrator shall notify the owner or operator of the facility in writing and:
(1) Promptly review the facility response plan;
(2) Require amendments to any response plan that does not meet the requirements of this section;
(3) Approve any response plan that meets the requirements of this section; and
(4) Review each response plan periodically thereafter on a schedule established by the Regional Administrator provided that the period between plan reviews does not exceed five years.
(d)(1) The owner or operator of a facility for which a response plan is required under this part shall revise and resubmit revised portions of the response plan within 60 days of each facility change that materially may affect the response to a worst case discharge, including:
(i) A change in the facility’s configuration that materially alters the information included in the response plan;
(ii) A change in the type of oil handled, stored, or transferred that materially alters the required response resources;
(iii) A material change in capabilities of the oil spill removal organization(s) that provide equipment and personnel to respond to discharges of oil described in paragraph (h)(5) of this section;
(iv) A material change in the facility’s spill prevention and response equipment or emergency response procedures; and
(v) Any other changes that materially affect the implementation of the response plan.
(2) Except as provided in paragraph (d)(1) of this section, amendments to personnel and telephone number lists included in the response plan and a change in the oil spill removal organization(s) that does not result in a material change in support capabilities do not require approval by the Regional Administrator. Facility owners or operators shall provide a copy of such changes to the Regional Administrator as the revisions occur.
(3) The owner or operator of a facility that submits changes to a response plan as provided in paragraph (d)(1) or (d)(2) of this section shall provide the EPA-issued facility identification number (where one has been assigned) with the changes.
(4) The Regional Administrator shall review for approval changes to a response plan submitted pursuant to paragraph (d)(1) of this section for a facility determined pursuant to paragraph (f)(3) of this section to have the potential to cause significant and substantial harm to the environment.
(e) If the owner or operator of a facility determines pursuant to paragraph (a)(2) of this section that the facility could not, because of its location, reasonably be expected to cause substantial harm to the environment by discharging oil into or on the navigable waters or adjoining shorelines, the owner or operator shall complete and maintain at the facility the certification form contained in appendix C to this part and, in the event an alternative formula that is comparable to one contained in appendix C to this part is used to evaluate the criterion in paragraph (f)(1)(ii)(B) or (f)(1)(ii)(C) of this section, the owner or operator shall attach documentation to the certification form that demonstrates the reliability and analytical soundness of the comparable formula and shall notify the Regional Administrator in writing that an alternative formula was used.
(f)(1) A facility could, because of its location, reasonably be expected to cause substantial harm to the environment by discharging oil into or on the navigable waters or adjoining shorelines pursuant to paragraph (a)(2) of this section, if it meets any of the following criteria applied in accordance with the flowchart contained in attachment C-I to appendix C to this part:
(i) The facility transfers oil over water to or from vessels and has a total oil storage capacity greater than or equal to 42,000 gallons; or
(ii) The facility’s total oil storage capacity is greater than or equal to 1 million gallons, and one of the following is true:
(A) The facility does not have secondary containment for each aboveground storage area sufficiently large to contain the capacity of the largest aboveground oil storage tank within each storage area plus sufficient freeboard to allow for precipitation;
(B) The facility is located at a distance (as calculated using the appropriate formula in appendix C to this part or a comparable formula) such that a discharge from the facility could cause injury to fish and wildlife and sensitive environments. For further description of fish and wildlife and sensitive environments, see Appendices I, II, and III of the “Guidance for Facility and Vessel Response Plans: Fish and Wildlife and Sensitive Environments” (see appendix E to this part, section 13, for availability) and the applicable Area Contingency Plan prepared pursuant to section 311(j)(4) of the Clean Water Act;
(C) The facility is located at a distance (as calculated using the appropriate formula in appendix C to this part or a comparable formula) such that a discharge from the facility would shut down a public drinking water intake; or
(D) The facility has had a reportable oil discharge in an amount greater than or equal to 10,000 gallons within the last 5 years.
(2)(i) To determine whether a facility could, because of its location, reasonably be expected to cause substantial harm to the environment by discharging oil into or on the navigable waters or adjoining shorelines pursuant to paragraph (b) of this section, the Regional Administrator shall consider the following:
(A) Type of transfer operation;
(B) Oil storage capacity;
(C) Lack of secondary containment;
(D) Proximity to fish and wildlife and sensitive environments and other areas determined by the Regional Administrator to possess ecological value;
(E) Proximity to drinking water intakes;
(F) Spill history; and
(G) Other site-specific characteristics and environmental factors that the Regional Administrator determines to be relevant to protecting the environment from harm by discharges of oil into or on navigable waters or adjoining shorelines.
(ii) Any person, including a member of the public or any representative from a Federal, State, or local agency who believes that a facility subject to this section could, because of its location, reasonably be expected to cause substantial harm to the environment by discharging oil into or on the navigable waters or adjoining shorelines may petition the Regional Administrator to determine whether the facility meets the criteria in paragraph (f)(2)(i) of this section. Such petition shall include a discussion of how the factors in paragraph (f)(2)(i) of this section apply to the facility in question. The RA shall consider such petitions and respond in an appropriate amount of time.
(3) To determine whether a facility could, because of its location, reasonably be expected to cause significant and substantial harm to the environment by discharging oil into or on the navigable waters or adjoining shorelines, the Regional Administrator may consider the factors in paragraph (f)(2) of this section as well as the following:
(i) Frequency of past discharges;
(ii) Proximity to navigable waters;
(iii) Age of oil storage tanks; and
(iv) Other facility-specific and Region-specific information, including local impacts on public health.
(g)(1) All facility response plans shall be consistent with the requirements of the National Oil and Hazardous Substance Pollution Contingency Plan (40 CFR part 300) and applicable Area Contingency Plans prepared pursuant to section 311(j)(4) of the Clean Water Act. The facility response plan should be coordinated with the local emergency response plan developed by the local emergency planning committee under section 303 of Title III of the Superfund Amendments and Reauthorization Act of 1986 (42 U.S.C. 11001 et seq.). Upon request, the owner or operator should provide a copy of the facility response plan to the local emergency planning committee or State emergency response commission.
(2) The owner or operator shall review relevant portions of the National Oil and Hazardous Substances Pollution Contingency Plan and applicable Area Contingency Plan annually and, if necessary, revise the facility response plan to ensure consistency with these plans.
(3) The owner or operator shall review and update the facility response plan periodically to reflect changes at the facility.
(h) A response plan shall follow the format of the model facility-specific response plan included in appendix F to this part, unless you have prepared an equivalent response plan acceptable to the Regional Administrator to meet State or other Federal requirements. A response plan that does not follow the specified format in appendix F to this part shall have an emergency response action plan as specified in paragraphs (h)(1) of this section and be supplemented with a cross-reference section to identify the location of the elements listed in paragraphs (h)(2) through (h)(10) of this section. To meet the requirements of this part, a response plan shall address the following elements, as further described in appendix F to this part:
(1) Emergency response action plan. The response plan shall include an emergency response action plan in the format specified in paragraphs (h)(1)(i) through (viii) of this section that is maintained in the front of the response plan, or as a separate document accompanying the response plan, and that includes the following information:
(i) The identity and telephone number of a qualified individual having full authority, including contracting authority, to implement removal actions;
(ii) The identity of individuals or organizations to be contacted in the event of a discharge so that immediate communications between the qualified individual identified in paragraph (h)(1) of this section and the appropriate Federal officials and the persons providing response personnel and equipment can be ensured;
(iii) A description of information to pass to response personnel in the event of a reportable discharge;
(iv) A description of the facility’s response equipment and its location;
(v) A description of response personnel capabilities, including the duties of persons at the facility during a response action and their response times and qualifications;
(vi) Plans for evacuation of the facility and a reference to community evacuation plans, as appropriate;
(vii) A description of immediate measures to secure the source of the discharge, and to provide adequate containment and drainage of discharged oil; and
(viii) A diagram of the facility.
(2) Facility information. The response plan shall identify and discuss the location and type of the facility, the identity and tenure of the present owner and operator, and the identity of the qualified individual identified in paragraph (h)(1) of this section.
(3) Information about emergency response. The response plan shall include:
(i) The identity of private personnel and equipment necessary to remove to the maximum extent practicable a worst case discharge and other discharges of oil described in paragraph (h)(5) of this section, and to mitigate or prevent a substantial threat of a worst case discharge (To identify response resources to meet the facility response plan requirements of this section, owners or operators shall follow appendix E to this part or, where not appropriate, shall clearly demonstrate in the response plan why use of appendix E of this part is not appropriate at the facility and make comparable arrangements for response resources);
(ii) Evidence of contracts or other approved means for ensuring the availability of such personnel and equipment;
(iii) The identity and the telephone number of individuals or organizations to be contacted in the event of a discharge so that immediate communications between the qualified individual identified in paragraph (h)(1) of this section and the appropriate Federal official and the persons providing response personnel and equipment can be ensured;
(iv) A description of information to pass to response personnel in the event of a reportable discharge;
(v) A description of response personnel capabilities, including the duties of persons at the facility during a response action and their response times and qualifications;
(vi) A description of the facility’s response equipment, the location of the equipment, and equipment testing;
(vii) Plans for evacuation of the facility and a reference to community evacuation plans, as appropriate;
(viii) A diagram of evacuation routes; and
(ix) A description of the duties of the qualified individual identified in paragraph (h)(1) of this section, that include:
(A) Activate internal alarms and hazard communication systems to notify all facility personnel;
(B) Notify all response personnel, as needed;
(C) Identify the character, exact source, amount, and extent of the release, as well as the other items needed for notification;
(D) Notify and provide necessary information to the appropriate Federal, State, and local authorities with designated response roles, including the National Response Center, State Emergency Response Commission, and Local Emergency Planning Committee;
(E) Assess the interaction of the discharged substance with water and/or other substances stored at the facility and notify response personnel at the scene of that assessment;
(F) Assess the possible hazards to human health and the environment due to the release. This assessment must consider both the direct and indirect effects of the release (i.e., the effects of any toxic, irritating, or asphyxiating gases that may be generated, or the effects of any hazardous surface water runoffs from water or chemical agents used to control fire and heat-induced explosion);
(G) Assess and implement prompt removal actions to contain and remove the substance released;
(H) Coordinate rescue and response actions as previously arranged with all response personnel;
(I) Use authority to immediately access company funding to initiate cleanup activities; and
(J) Direct cleanup activities until properly relieved of this responsibility.
(4) Hazard evaluation. The response plan shall discuss the facility’s known or reasonably identifiable history of discharges reportable under 40 CFR part 110 for the entire life of the facility and shall identify areas within the facility where discharges could occur and what the potential effects of the discharges would be on the affected environment. To assess the range of areas potentially affected, owners or operators shall, where appropriate, consider the distance calculated in paragraph (f)(1)(ii) of this section to determine whether a facility could, because of its location, reasonably be expected to cause substantial harm to the environment by discharging oil into or on the navigable waters or adjoining shorelines.
(5) Response planning levels. The response plan shall include discussion of specific planning scenarios for:
(i) A worst case discharge, as calculated using the appropriate worksheet in appendix D to this part. In cases where the Regional Administrator determines that the worst case discharge volume calculated by the facility is not appropriate, the Regional Administrator may specify the worst case discharge amount to be used for response planning at the facility. For complexes, the worst case planning quantity shall be the larger of the amounts calculated for each component of the facility;
(ii) A discharge of 2,100 gallons or less, provided that this amount is less than the worst case discharge amount. For complexes, this planning quantity shall be the larger of the amounts calculated for each component of the facility; and
(iii) A discharge greater than 2,100 gallons and less than or equal to 36,000 gallons or 10 percent of the capacity of the largest tank at the facility, whichever is less, provided that this amount is less than the worst case discharge amount. For complexes, this planning quantity shall be the larger of the amounts calculated for each component of the facility.
(6) Discharge detection systems. The response plan shall describe the procedures and equipment used to detect discharges.
(7) Plan implementation. The response plan shall describe:
(i) Response actions to be carried out by facility personnel or contracted personnel under the response plan to ensure the safety of the facility and to mitigate or prevent discharges described in paragraph (h)(5) of this section or the substantial threat of such discharges;
(ii) A description of the equipment to be used for each scenario;
(iii) Plans to dispose of contaminated cleanup materials; and
(iv) Measures to provide adequate containment and drainage of discharged oil.
(8) Self-inspection, drills/exercises, and response training. The response plan shall include:
(i) A checklist and record of inspections for tanks, secondary containment, and response equipment;
(ii) A description of the drill/exercise program to be carried out under the response plan as described in § 112.21;
(iii) A description of the training program to be carried out under the response plan as described in § 112.21; and
(iv) Logs of discharge prevention meetings, training sessions, and drills/exercises. These logs may be maintained as an annex to the response plan.
(9) Diagrams. The response plan shall include site plan and drainage plan diagrams.
(10) Security systems. The response plan shall include a description of facility security systems.
(11) Response plan cover sheet. The response plan shall include a completed response plan cover sheet provided in section 2.0 of appendix F to this part.
(i)(1) In the event the owner or operator of a facility does not agree with the Regional Administrator’s determination that the facility could, because of its location, reasonably be expected to cause substantial harm or significant and substantial harm to the environment by discharging oil into or on the navigable waters or adjoining shorelines, or that amendments to the facility response plan are necessary prior to approval, such as changes to the worst case discharge planning volume, the owner or operator may submit a request for reconsideration to the Regional Administrator and provide additional information and data in writing to support the request. The request and accompanying information must be submitted to the Regional Administrator within 60 days of receipt of notice of the Regional Administrator’s original decision. The Regional Administrator shall consider the request and render a decision as rapidly as practicable.
(2) In the event the owner or operator of a facility believes a change in the facility’s classification status is warranted because of an unplanned event or change in the facility’s characteristics (i.e., substantial harm or significant and substantial harm), the owner or operator may submit a request for reconsideration to the Regional Administrator and provide additional information and data in writing to support the request. The Regional Administrator shall consider the request and render a decision as rapidly as practicable.
(3) After a request for reconsideration under paragraph (i)(1) or (i)(2) of this section has been denied by the Regional Administrator, an owner or operator may appeal a determination made by the Regional Administrator. The appeal shall be made to the EPA Administrator and shall be made in writing within 60 days of receipt of the decision from the Regional Administrator that the request for reconsideration was denied. A complete copy of the appeal must be sent to the Regional Administrator at the time the appeal is made. The appeal shall contain a clear and concise statement of the issues and points of fact in the case. It also may contain additional information from the owner or operator, or from any other person. The EPA Administrator may request additional information from the owner or operator, or from any other person. The EPA Administrator shall render a decision as rapidly as practicable and shall notify the owner or operator of the decision.
§ 112.21 Facility response training and drills/exercises.
(a) The owner or operator of any facility required to prepare a facility response plan under § 112.20 shall develop and implement a facility response training program and a drill/exercise program that satisfy the requirements of this section. The owner or operator shall describe the programs in the response plan as provided in § 112.20(h)(8).
(b) The facility owner or operator shall develop a facility response training program to train those personnel involved in oil spill response activities. It is recommended that the training program be based on the USCG’s Training Elements for Oil Spill Response, as applicable to facility operations. An alternative program can also be acceptable subject to approval by the Regional Administrator.
(1) The owner or operator shall be responsible for the proper instruction of facility personnel in the procedures to respond to discharges of oil and in applicable oil spill response laws, rules, and regulations.
(2) Training shall be functional in nature according to job tasks for both supervisory and non-supervisory operational personnel.
(3) Trainers shall develop specific lesson plans on subject areas relevant to facility personnel involved in oil spill response and cleanup.
(c) The facility owner or operator shall develop a program of facility response drills/exercises, including evaluation procedures. A program that follows the National Preparedness for Response Exercise Program (PREP) (see appendix E to this part, section 13, for availability) will be deemed satisfactory for purposes of this section. An alternative program can also be acceptable subject to approval by the Regional Administrator.
Appendix A to Part 112 – Memorandum of Understanding Between the Secretary of Transportation and the Administrator of the Environmental Protection Agency
The Environmental Protection Agency and the Department of Transportation agree that for the purposes of Executive Order 11548, the term:
(1) Non-transportation-related onshore and offshore facilities means:
(A) Fixed onshore and offshore oil well drilling facilities including all equipment and appurtenances related thereto used in drilling operations for exploratory or development wells, but excluding any terminal facility, unit or process integrally associated with the handling or transferring of oil in bulk to or from a vessel.
(B) Mobile onshore and offshore oil well drilling platforms, barges, trucks, or other mobile facilities including all equipment and appurtenances related thereto when such mobile facilities are fixed in position for the purpose of drilling operations for exploratory or development wells, but excluding any terminal facility, unit or process integrally associated with the handling or transferring of oil in bulk to or from a vessel.
(C) Fixed onshore and offshore oil production structures, platforms, derricks, and rigs including all equipment and appurtenances related thereto, as well as completed wells and the wellhead separators, oil separators, and storage facilities used in the production of oil, but excluding any terminal facility, unit or process integrally associated with the handling or transferring of oil in bulk to or from a vessel.
(D) Mobile onshore and offshore oil production facilities including all equipment and appurtenances related thereto as well as completed wells and wellhead equipment, piping from wellheads to oil separators, oil separators, and storage facilities used in the production of oil when such mobile facilities are fixed in position for the purpose of oil production operations, but excluding any terminal facility, unit or process integrally associated with the handling or transferring of oil in bulk to or from a vessel.
(E) Oil refining facilities including all equipment and appurtenances related thereto as well as in-plant processing units, storage units, piping, drainage systems and waste treatment units used in the refining of oil, but excluding any terminal facility, unit or process integrally associated with the handling or transferring of oil in bulk to or from a vessel.
(F) Oil storage facilities including all equipment and appurtenances related thereto as well as fixed bulk plant storage, terminal oil storage facilities, consumer storage, pumps and drainage systems used in the storage of oil, but excluding inline or breakout storage tanks needed for the continuous operation of a pipeline system and any terminal facility, unit or process integrally associated with the handling or transferring of oil in bulk to or from a vessel.
(G) Industrial, commercial, agricultural or public facilities which use and store oil, but excluding any terminal facility, unit or process integrally associated with the handling or transferring of oil in bulk to or from a vessel.
(H) Waste treatment facilities including in-plant pipelines, effluent discharge lines, and storage tanks, but excluding waste treatment facilities located on vessels and terminal storage tanks and appurtenances for the reception of oily ballast water or tank washings from vessels and associated systems used for off-loading vessels.
(I) Loading racks, transfer hoses, loading arms and other equipment which are appurtenant to a nontransportation-related facility or terminal facility and which are used to transfer oil in bulk to or from highway vehicles or railroad cars.
(J) Highway vehicles and railroad cars which are used for the transport of oil exclusively within the confines of a nontransportation-related facility and which are not intended to transport oil in interstate or intrastate commerce.
(K) Pipeline systems which are used for the transport of oil exclusively within the confines of a nontransportation-related facility or terminal facility and which are not intended to transport oil in interstate or intrastate commerce, but excluding pipeline systems used to transfer oil in bulk to or from a vessel.
(2) Transportation-related onshore and offshore facilities means:
(A) Onshore and offshore terminal facilities including transfer hoses, loading arms and other equipment and appurtenances used for the purpose of handling or transferring oil in bulk to or from a vessel as well as storage tanks and appurtenances for the reception of oily ballast water or tank washings from vessels, but excluding terminal waste treatment facilities and terminal oil storage facilities.
(B) Transfer hoses, loading arms and other equipment appurtenant to a non-transportation-related facility which is used to transfer oil in bulk to or from a vessel.
(C) Interstate and intrastate onshore and offshore pipeline systems including pumps and appurtenances related thereto as well as in-line or breakout storage tanks needed for the continuous operation of a pipeline system, and pipelines from onshore and offshore oil production facilities, but excluding onshore and offshore piping from wellheads to oil separators and pipelines which are used for the transport of oil exclusively within the confines of a nontransportation-related facility or terminal facility and which are not intended to transport oil in interstate or intrastate commerce or to transfer oil in bulk to or from a vessel.
(D) Highway vehicles and railroad cars which are used for the transport of oil in interstate or intrastate commerce and the equipment and appurtenances related thereto, and equipment used for the fueling of locomotive units, as well as the rights-of-way on which they operate. Excluded are highway vehicles and railroad cars and motive power used exclusively within the confines of a nontransportation-related facility or terminal facility and which are not intended for use in interstate or intrastate commerce.
Appendix B to Part 112 – Memorandum of Understanding Among the Secretary of the Interior, Secretary of Transportation, and Administrator of the Environmental Protection Agency
This Memorandum of Understanding (MOU) establishes the jurisdictional responsibilities for offshore facilities, including pipelines, pursuant to section 311 (j)(1)(c), (j)(5), and (j)(6)(A) of the Clean Water Act (CWA), as amended by the Oil Pollution Act of 1990 (Public Law 101-380). The Secretary of the Department of the Interior (DOI), Secretary of the Department of Transportation (DOT), and Administrator of the Environmental Protection Agency (EPA) agree to the division of responsibilities set forth below for spill prevention and control, response planning, and equipment inspection activities pursuant to those provisions.
Executive Order (E.O.) 12777 (56 FR 54757) delegates to DOI, DOT, and EPA various responsibilities identified in section 311(j) of the CWA. Sections 2(b)(3), 2(d)(3), and 2(e)(3) of E.O. 12777 assigned to DOI spill prevention and control, contingency planning, and equipment inspection activities associated with offshore facilities. Section 311(a)(11) defines the term “offshore facility” to include facilities of any kind located in, on, or under navigable waters of the United States. By using this definition, the traditional DOI role of regulating facilities on the Outer Continental Shelf is expanded by E.O. 12777 to include inland lakes, rivers, streams, and any other inland waters.
Pursuant to section 2(i) of E.O. 12777, DOI redelegates, and EPA and DOT agree to assume, the functions vested in DOI by sections 2(b)(3), 2(d)(3), and 2(e)(3) of E.O. 12777 as set forth below. For purposes of this MOU, the term “coast line” shall be defined as in the Submerged Lands Act (43 U.S.C. 1301(c)) to mean “the line of ordinary low water along that portion of the coast which is in direct contact with the open sea and the line marking the seaward limit of inland waters.”
1. To EPA, DOI redelegates responsibility for non-transportation-related offshore facilities located landward of the coast line.
2. To DOT, DOI redelegates responsibility for transportation-related facilities, including pipelines, located landward of the coast line. The DOT retains jurisdiction for deepwater ports and their associated seaward pipelines, as delegated by E.O. 12777.
3. The DOI retains jurisdiction over facilities, including pipelines, located seaward of the coast line, except for deepwater ports and associated seaward pipelines delegated by E.O. 12777 to DOT.
This MOU is effective on the date of the final execution by the indicated signatories.
1. The DOI, DOT, and EPA may agree in writing to exceptions to this MOU on a facility-specific basis. Affected parties will receive notification of the exceptions.
2. Nothing in this MOU is intended to replace, supersede, or modify any existing agreements between or among DOI, DOT, or EPA.
Any party to this agreement may propose modifications by submitting them in writing to the heads of the other agency/department. No modification may be adopted except with the consent of all parties. All parties shall indicate their consent to or disagreement with any proposed modification within 60 days of receipt. Upon the request of any party, representatives of all parties shall meet for the purpose of considering exceptions or modifications to this agreement. This MOU may be terminated only with the mutual consent of all parties.
Dated: November 8, 1993.
Secretary of the Interior.
Dated: December 14, 1993.
Secretary of Transportation.
Dated: February 3, 1994.
Administrator, Environmental Protection Agency.
Appendix C to Part 112 – Substantial Harm Criteria
The flowchart provided in Attachment C-I to this appendix shows the decision tree with the criteria to identify whether a facility “could reasonably be expected to cause substantial harm to the environment by discharging into or on the navigable waters or adjoining shorelines.” In addition, the Regional Administrator has the discretion to identify facilities that must prepare and submit facility-specific response plans to EPA.
1.1.1 Great Lakes means Lakes Superior, Michigan, Huron, Erie, and Ontario, their connecting and tributary waters, the Saint Lawrence River as far as Saint Regis, and adjacent port areas.
1.1.2 Higher Volume Port Areas include
(1) Boston, MA;
(2) New York, NY;
(3) Delaware Bay and River to Philadelphia, PA;
(4) St. Croix, VI;
(5) Pascagoula, MS;
(6) Mississippi River from Southwest Pass, LA to Baton Rouge, LA;
(7) Louisiana Offshore Oil Port (LOOP), LA;
(8) Lake Charles, LA;
(9) Sabine-Neches River, TX;
(10) Galveston Bay and Houston Ship Channel, TX;
(11) Corpus Christi, TX;
(12) Los Angeles/Long Beach Harbor, CA;
(13) San Francisco Bay, San Pablo Bay, Carquinez Strait, and Suisun Bay to Antioch, CA;
(14) Straits of Juan de Fuca from Port Angeles, WA to and including Puget Sound, WA;
(15) Prince William Sound, AK; and
(16) Others as specified by the Regional Administrator for any EPA Region.
1.1.3 Inland Area means the area shoreward of the boundary lines defined in 46 CFR part 7, except in the Gulf of Mexico. In the Gulf of Mexico, it means the area shoreward of the lines of demarcation (COLREG lines as defined in 33 CFR 80.740-80.850). The inland area does not include the Great Lakes.
1.1.4 Rivers and Canals means a body of water confined within the inland area, including the Intracoastal Waterways and other waterways artificially created for navigating that have project depths of 12 feet or less.
A facility that has the potential to cause substantial harm to the environment in the event of a discharge must prepare and submit a facility-specific response plan to EPA in accordance with appendix F to this part. A description of the screening criteria for the substantial harm flowchart is provided below:
2.1 Non-Transportation-Related Facilities With a Total Oil Storage Capacity Greater Than or Equal to 42,000 Gallons Where Operations Include Over-Water Transfers of Oil. A non-transportation-related facility with a total oil storage capacity greater than or equal to 42,000 gallons that transfers oil over water to or from vessels must submit a response plan to EPA. Daily oil transfer operations at these types of facilities occur between barges and vessels and onshore bulk storage tanks over open water. These facilities are located adjacent to navigable water.
2.2 Lack of Adequate Secondary Containment at Facilities With a Total Oil Storage Capacity Greater Than or Equal to 1 Million Gallons. Any facility with a total oil storage capacity greater than or equal to 1 million gallons without secondary containment sufficiently large to contain the capacity of the largest aboveground oil storage tank within each area plus sufficient freeboard to allow for precipitation must submit a response plan to EPA. Secondary containment structures that meet the standard of good engineering practice for the purposes of this part include berms, dikes, retaining walls, curbing, culverts, gutters, or other drainage systems.
2.3 Proximity to Fish and Wildlife and Sensitive Environments at Facilities With a Total Oil Storage Capacity Greater Than or Equal to 1 Million Gallons. A facility with a total oil storage capacity greater than or equal to 1 million gallons must submit its response plan if it is located at a distance such that a discharge from the facility could cause injury (as defined at 40 CFR 112.2) to fish and wildlife and sensitive environments. For further description of fish and wildlife and sensitive environments, see Appendices I, II, and III to DOC/NOAA’s “Guidance for Facility and Vessel Response Plans: Fish and Wildlife and Sensitive Environments” (see appendix E to this part, section 13, for availability) and the applicable Area Contingency Plan. Facility owners or operators must determine the distance at which an oil discharge could cause injury to fish and wildlife and sensitive environments using the appropriate formula presented in Attachment C-III to this appendix or a comparable formula.
2.4 Proximity to Public Drinking Water Intakes at Facilities with a Total Oil Storage Capacity Greater than or Equal to 1 Million Gallons A facility with a total oil storage capacity greater than or equal to 1 million gallons must submit its response plan if it is located at a distance such that a discharge from the facility would shut down a public drinking water intake, which is analogous to a public water system as described at 40 CFR 143.2(c). The distance at which an oil discharge from an SPCC-regulated facility would shut down a public drinking water intake shall be calculated using the appropriate formula presented in Attachment C-III to this appendix or a comparable formula.
2.5 Facilities That Have Experienced Reportable Oil Discharges in an Amount Greater Than or Equal to 10,000 Gallons Within the Past 5 Years and That Have a Total Oil Storage Capacity Greater Than or Equal to 1 Million Gallons. A facility’s oil spill history within the past 5 years shall be considered in the evaluation for substantial harm. Any facility with a total oil storage capacity greater than or equal to 1 million gallons that has experienced a reportable oil discharge in an amount greater than or equal to 10,000 gallons within the past 5 years must submit a response plan to EPA.
If the facility does not meet the substantial harm criteria listed in Attachment C-I to this appendix, the owner or operator shall complete and maintain at the facility the certification form contained in Attachment C-II to this appendix. In the event an alternative formula that is comparable to the one in this appendix is used to evaluate the substantial harm criteria, the owner or operator shall attach documentation to the certification form that demonstrates the reliability and analytical soundness of the comparable formula and shall notify the Regional Administrator in writing that an alternative formula was used.
Chow, V.T. 1959. Open Channel Hydraulics. McGraw Hill.
USCG IFR (58 FR 7353, February 5, 1993). This document is available through EPA’s rulemaking docket as noted in appendix E to this part, section 13.
1. Does the facility transfer oil over water to or from vessels and does the facility have a total oil storage capacity greater than or equal to 42,000 gallons?
Yes ____ No ____
2. Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and does the facility lack secondary containment that is sufficiently large to contain the capacity of the largest aboveground oil storage tank plus sufficient freeboard to allow for precipitation within any aboveground oil storage tank area?
Yes ____ No ____
3. Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and is the facility located at a distance (as calculated using the appropriate formula in Attachment C-III to this appendix or a comparable formula
Yes ____ No ____
4. Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and is the facility located at a distance (as calculated using the appropriate formula in Attachment C-III to this appendix or a comparable formula
Yes ____ No ____
5. Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and has the facility experienced a reportable oil discharge in an amount greater than or equal to 10,000 gallons within the last 5 years?
Yes ____ No ____
I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document, and that based on my inquiry of those individuals responsible for obtaining this information, I believe that the submitted information is true, accurate, and complete.
1.1 The facility owner or operator must evaluate whether the facility is located at a distance such that a discharge from the facility could cause injury to fish and wildlife and sensitive environments or disrupt operations at a public drinking water intake. To quantify that distance, EPA considered oil transport mechanisms over land and on still, tidal influence, and moving navigable waters. EPA has determined that the primary concern for calculation of a planning distance is the transport of oil in navigable waters during adverse weather conditions. Therefore, two formulas have been developed to determine distances for planning purposes from the point of discharge at the facility to the potential site of impact on moving and still waters, respectively. The formula for oil transport on moving navigable water is based on the velocity of the water body and the time interval for arrival of response resources. The still water formula accounts for the spread of discharged oil over the surface of the water. The method to determine oil transport on tidal influence areas is based on the type of oil discharged and the distance down current during ebb tide and up current during flood tide to the point of maximum tidal influence.
1.2 EPA’s formulas were designed to be simple to use. However, facility owners or operators may calculate planning distances using more sophisticated formulas, which take into account broader scientific or engineering principles, or local conditions. Such comparable formulas may result in different planning distances than EPA’s formulas. In the event that an alternative formula that is comparable to one contained in this appendix is used to evaluate the criterion in 40 CFR 112.20(f)(1)(ii)(B) or (f)(1)(ii)(C), the owner or operator shall attach documentation to the response plan cover sheet contained in appendix F to this part that demonstrates the reliability and analytical soundness of the alternative formula and shall notify the Regional Administrator in writing that an alternative formula was used.
1.3 A regulated facility may meet the criteria for the potential to cause substantial harm to the environment without having to perform a planning distance calculation. For facilities that meet the substantial harm criteria because of inadequate secondary containment or oil spill history, as listed in the flowchart in Attachment C-I to this appendix, calculation of the planning distance is unnecessary. For facilities that do not meet the substantial harm criteria for secondary containment or oil spill history as listed in the flowchart, calculation of a planning distance for proximity to fish and wildlife and sensitive environments and public drinking water intakes is required, unless it is clear without performing the calculation (e.g., the facility is located in a wetland) that these areas would be impacted.
1.4 A facility owner or operator who must perform a planning distance calculation on navigable water is only required to do so for the type of navigable water conditions (i.e., moving water, still water, or tidal- influenced water) applicable to the facility. If a facility owner or operator determines that more than one type of navigable water condition applies, then the facility owner or operator is required to perform a planning distance calculation for each navigable water type to determine the greatest single distance that oil may be transported. As a result, the final planning distance for oil transport on water shall be the greatest individual distance rather than a summation of each calculated planning distance.
1.5 The planning distance formula for transport on moving waterways contains three variables: the velocity of the navigable water (v), the response time interval (t), and a conversion factor (c). The velocity, v, is determined by using the Chezy-Manning equation, which, in this case, models the flood flow rate of water in open channels. The Chezy-Manning equation contains three variables which must be determined by facility owners or operators. Manning’s Roughness Coefficient (for flood flow rates), n, can be determined from Table 1 of this attachment. The hydraulic radius, r, can be estimated using the average mid-channel depth from charts provided by the sources listed in Table 2 of this attachment. The average slope of the river, s, can be determined using topographic maps that can be ordered from the U.S. Geological Survey, as listed in Table 2 of this attachment.
1.6 Table 3 of this attachment contains specified time intervals for estimating the arrival of response resources at the scene of a discharge. Assuming no prior planning, response resources should be able to arrive at the discharge site within 12 hours of the discovery of any oil discharge in Higher Volume Port Areas and within 24 hours in Great Lakes and all other river, canal, inland, and nearshore areas. The specified time intervals in Table 3 of appendix C are to be used only to aid in the identification of whether a facility could cause substantial harm to the environment. Once it is determined that a plan must be developed for the facility, the owner or operator shall reference appendix E to this part to determine appropriate resource levels and response times. The specified time intervals of this appendix include a 3-hour time period for deployment of boom and other response equipment. The Regional Administrator may identify additional areas as appropriate.
2.1 The facility owner or operator must use the following formula or a comparable formula as described in § 112.20(a)(3) to calculate the planning distance for oil transport on moving navigable water:
2.2 Chezy-Manning’s equation is used to determine velocity:
Table 1 – Manning’s Roughness Coefficient for Natural Streams
| Stream description | Roughness coefficient (n) |
|---|---|
| Minor Streams (Top Width | |
| Clean: | |
| Straight | 0.03 |
| Winding | 0.04 |
| Sluggish (Weedy, deep pools): | |
| No trees or brush | 0.06 |
| Trees and/or brush | 0.10 |
| Major Streams (Top Width >100 ft.) | |
| Regular section: | |
| (No boulders/brush) | 0.035 |
| Irregular section: | |
| (Brush) | 0.05 |
2.3 The average slope of the river (s) can be determined from the topographic maps using the following steps:
(1) Locate the facility on the map.
(2) Find the Normal Pool Elevation at the point of discharge from the facility into the water (A).
(3) Find the Normal Pool Elevation of the public drinking water intake or fish and wildlife and sensitive environment located downstream (B) (Note: The owner or operator should use a minimum of 20 miles downstream as a cutoff to obtain the average slope if the location of a specific public drinking water intake or fish and wildlife and sensitive environment is unknown).
(4) If the Normal Pool Elevation is not available, the elevation contours can be used to find the slope. Determine elevation of the water at the point of discharge from the facility (A). Determine the elevation of the water at the appropriate distance downstream (B). The formula presented below can be used to calculate the slope.
(5) Determine the distance (in miles) between the facility and the public drinking water intake or fish and wildlife and sensitive environments (C).
(6) Use the following formula to find the slope, which will be a unitless value: Average Slope=[(A−B) (ft)/C (miles)] × [1 mile/5280 feet]
2.4 If it is not feasible to determine the slope and mid-channel depth by the Chezy-Manning equation, then the river velocity can be approximated on- site. A specific length, such as 100 feet, can be marked off along the shoreline. A float can be dropped into the stream above the mark, and the time required for the float to travel the distance can be used to determine the velocity in feet per second. However, this method will not yield an average velocity for the length of the stream, but a velocity only for the specific location of measurement. In addition, the flow rate will vary depending on weather conditions such as wind and rainfall. It is recommended that facility owners or operators repeat the measurement under a variety of conditions to obtain the most accurate estimate of the surface water velocity under adverse weather conditions.
2.5 The planning distance calculations for moving and still navigable waters are based on worst case discharges of persistent oils. Persistent oils are of concern because they can remain in the water for significant periods of time and can potentially exist in large quantities downstream. Owners or operators of facilities that store persistent as well as non-persistent oils may use a comparable formula. The volume of oil discharged is not included as part of the planning distance calculation for moving navigable waters. Facilities that will meet this substantial harm criterion are those with facility capacities greater than or equal to 1 million gallons. It is assumed that these facilities are capable of having an oil discharge of sufficient quantity to cause injury to fish and wildlife and sensitive environments or shut down a public drinking water intake. While owners or operators of transfer facilities that store greater than or equal to 42,000 gallons are not required to use a planning distance formula for purposes of the substantial harm criteria, they should use a planning distance calculation in the development of facility-specific response plans.
Table 3 – Specified Time Intervals
| Operating areas | Substantial harm planning time (hrs) |
|---|---|
| Higher volume port area | 12 hour arrival + 3 hour deployment = 15 hours. |
| Great Lakes | 24 hour arrival + 3 hour deployment = 27 hours. |
| All other rivers and canals, inland, and nearshore areas | 24 hour arrival + 3 hour deployment = 27 hours. |
2.6 Example of the Planning Distance Calculation for Oil Transport on Moving Navigable Waters. The following example provides a sample calculation using the planning distance formula for a facility discharging oil into the Monongahela River:
(1) Solve for v by evaluating n, r, and s for the Chezy-Manning equation:
Find the roughness coefficient, n, on Table 1 of this attachment for a regular section of a major stream with a top width greater than 100 feet. The top width of the river can be found from the topographic map.
The average mid-channel depth is found by averaging the mid-channel depth for each mile along the length of the river between the facility and the public drinking water intake or the fish or wildlife or sensitive environment (or 20 miles downstream if applicable). This value is multiplied by 0.667 to obtain the hydraulic radius. The mid-channel depth is found by obtaining values for r and s from the sources shown in Table 2 for the Monongahela River.
(2) Find t from Table 3 of this attachment. The Monongahela River’s resource response time is 27 hours.
(3) Solve for planning distance, d:
3.1 For bodies of water including lakes or ponds that do not have a measurable velocity, the spreading of the oil over the surface must be considered. Owners or operators of facilities located next to still water bodies may use a comparable means of calculating the planning distance. If a comparable formula is used, documentation of the reliability and analytical soundness of the comparable calculation must be attached to the response plan cover sheet.
3.2 Example of the Planning Distance Calculation for Oil Transport on Still Water. To assist those facilities which could potentially discharge into a still body of water, the following analysis was performed to provide an example of the type of formula that may be used to calculate the planning distance. For this example, a worst case discharge of 2,000,000 gallons is used.
(1) The surface area in square feet covered by an oil discharge on still water, A1, can be determined by the following formula,
(2) The spreading formula is based on the theoretical condition that the oil will spread uniformly in all directions forming a circle. In reality, the outfall of the discharge will direct the oil to the surface of the water where it intersects the shoreline. Although the oil will not spread uniformly in all directions, it is assumed that the discharge will spread from the shoreline into a semi-circle (this assumption does not account for winds or wave action).
(3) The area of a circle=† r
(4) To account for the assumption that oil will spread in a semi-circular shape, the area of a circle is divided by 2 and is designated as A
(5) To estimate the distance that the oil will travel, use the times required for response resources to arrive at different geographic locations as shown in Table 3 of this attachment.
(6) The total distance that the oil will travel from the point of discharge, including the distance due to spreading, is calculated as follows:
4.1 The planning distance method for tidal influence navigable water is based on worst case discharges of persistent and non-persistent oils. Persistent oils are of primary concern because they can potentially cause harm over a greater distance. For persistent oils discharged into tidal waters, the planning distance is 15 miles from the facility down current during ebb tide and to the point of maximum tidal influence or 15 miles, whichever is less, during flood tide.
4.2 For non-persistent oils discharged into tidal waters, the planning distance is 5 miles from the facility down current during ebb tide and to the point of maximum tidal influence or 5 miles, whichever is less, during flood tide.
4.3 Example of Determining the Planning Distance for Two Types of Navigable Water Conditions. Below is an example of how to determine the proper planning distance when a facility could impact two types of navigable water conditions: moving water and tidal water.
(1) Facility X stores persistent oil and is located downstream from locks along a slow moving river which is affected by tides. The river velocity, v, is determined to be 0.5 feet/second from the Chezy-Manning equation used to calculate oil transport on moving navigable waters. The specified time interval, t, obtained from Table 3 of this attachment for river areas is 27 hours. Therefore, solving for the planning distance, d:
(2) However, the planning distance for maximum tidal influence down current during ebb tide is 15 miles, which is greater than the calculated 9.18 miles. Therefore, 15 miles downstream is the appropriate planning distance for this facility.
5.1 Facility owners or operators must evaluate the potential for oil to be transported over land to navigable waters of the United States. The owner or operator must evaluate the likelihood that portions of a worst case discharge would reach navigable waters via open channel flow or from sheet flow across the land, or be prevented from reaching navigable waters when trapped in natural or man-made depressions excluding secondary containment structures.
5.2 As discharged oil travels over land, it may enter a storm drain or open concrete channel intended for drainage. It is assumed that once oil reaches such an inlet, it will flow into the receiving navigable water. During a storm event, it is highly probable that the oil will either flow into the drainage structures or follow the natural contours of the land and flow into the navigable water. Expected minimum and maximum velocities are provided as examples of open concrete channel and pipe flow. The ranges listed below reflect minimum and maximum velocities used as design criteria.
5.3 Assuming a length of 0.5 mile from the point of discharge through an open concrete channel or concrete storm drain to a navigable water, the travel times (distance/velocity) are:
5.4 The distances that shall be considered to determine the planning distance are illustrated in Figure C-I of this attachment. The relevant distances can be described as follows:
5.5 A facility owner or operator whose nearest opportunity for discharge is located within 0.5 mile of a navigable water must complete the planning distance calculation (D3) for the type of navigable water near the facility or use a comparable formula.
5.6 A facility that is located at a distance greater than 0.5 mile from a navigable water must also calculate a planning distance (D3) if it is in close proximity (i.e., D1 is less than 0.5 mile and other factors are conducive to oil travel over land) to storm drains that flow to navigable waters. Factors to be considered in assessing oil transport over land to storm drains shall include the topography of the surrounding area, drainage patterns, man-made barriers (excluding secondary containment structures), and soil distribution and porosity. Storm drains or concrete drainage channels that are located in close proximity to the facility can provide a direct pathway to navigable waters, regardless of the length of the drainage pipe. If D1 is less than or equal to 0.5 mile, a discharge from the facility could pose substantial harm because the time to travel the distance from the storm drain to the navigable water (D2) is virtually instantaneous.
5.7 A facility’s proximity to fish and wildlife and sensitive environments not bordering a navigable water, as depicted as D4 in Figure C-I of this attachment, must also be considered, regardless of the distance from the facility to navigable waters. Factors to be considered in assessing oil transport over land to fish and wildlife and sensitive environments should include the topography of the surrounding area, drainage patterns, man-made barriers (excluding secondary containment structures), and soil distribution and porosity.
5.8 If a facility is not found to pose substantial harm to fish and wildlife and sensitive environments not bordering navigable waters via oil transport on land, then supporting documentation should be maintained at the facility. However, such documentation should be submitted with the response plan if a facility is found to pose substantial harm.
Appendix D to Part 112 – Determination of a Worst Case Discharge Planning Volume
1.1 An owner or operator is required to complete this worksheet if the facility meets the criteria, as presented in appendix C to this part, or it is determined by the RA that the facility could cause substantial harm to the environment. The calculation of a worst case discharge planning volume is used for emergency planning purposes, and is required in 40 CFR 112.20 for facility owners or operators who must prepare a response plan. When planning for the amount of resources and equipment necessary to respond to the worst case discharge planning volume, adverse weather conditions must be taken into consideration. An owner or operator is required to determine the facility’s worst case discharge planning volume from either part A of this appendix for an onshore storage facility, or part B of this appendix for an onshore production facility. The worksheet considers the provision of adequate secondary containment at a facility.
1.2 For onshore storage facilities and production facilities, permanently manifolded oil storage tanks are defined as tanks that are designed, installed, and/or operated in such a manner that the multiple tanks function as one storage unit (i.e., multiple tank volumes are equalized). In a worst case discharge scenario, a single failure could cause the discharge of the contents of more than one tank. The owner or operator must provide evidence in the response plan that tanks with common piping or piping systems are not operated as one unit. If such evidence is provided and is acceptable to the RA, the worst case discharge planning volume would be based on the capacity of the largest oil storage tank within a common secondary containment area or the largest oil storage tank within a single secondary containment area, whichever is greater. For permanently manifolded tanks that function as one oil storage unit, the worst case discharge planning volume would be based on the combined oil storage capacity of all manifolded tanks or the capacity of the largest single oil storage tank within a secondary containment area, whichever is greater. For purposes of this rule, permanently manifolded tanks that are separated by internal divisions for each tank are considered to be single tanks and individual manifolded tank volumes are not combined.
1.3 For production facilities, the presence of exploratory wells, production wells, and oil storage tanks must be considered in the calculation. Part B of this appendix takes these additional factors into consideration and provides steps for their inclusion in the total worst case discharge planning volume. Onshore oil production facilities may include all wells, flowlines, separation equipment, storage facilities, gathering lines, and auxiliary non-transportation-related equipment and facilities in a single geographical oil or gas field operated by a single operator. Although a potential worst case discharge planning volume is calculated within each section of the worksheet, the final worst case amount depends on the risk parameter that results in the greatest volume.
1.4 Marine transportation-related transfer facilities that contain fixed aboveground onshore structures used for bulk oil storage are jointly regulated by EPA and the U.S. Coast Guard (USCG), and are termed “complexes.” Because the USCG also requires response plans from transportation-related facilities to address a worst case discharge of oil, a separate calculation for the worst case discharge planning volume for USCG-related facilities is included in the USCG IFR (see appendix E to this part, section 13, for availability). All complexes that are jointly regulated by EPA and the USCG must compare both calculations for worst case discharge planning volume derived by using the EPA and USCG methodologies and plan for whichever volume is greater.
Part A of this worksheet is to be completed by the owner or operator of an SPCC-regulated facility (excluding oil production facilities) if the facility meets the criteria as presented in appendix C to this part, or if it is determined by the RA that the facility could cause substantial harm to the environment. If you are the owner or operator of a production facility, please proceed to part B of this worksheet.
For facilities containing only one aboveground oil storage tank, the worst case discharge planning volume equals the capacity of the oil storage tank. If adequate secondary containment (sufficiently large to contain the capacity of the aboveground oil storage tank plus sufficient freeboard to allow for precipitation) exists for the oil storage tank, multiply the capacity of the tank by 0.8.
(1) FINAL WORST CASE VOLUME: ____ GAL
(2) Do not proceed further.
Are all aboveground oil storage tanks or groups of aboveground oil storage tanks at the facility without adequate secondary containment?
A.2.1 If the answer is yes, the final worst case discharge planning volume equals the total aboveground oil storage capacity at the facility.
(1) FINAL WORST CASE VOLUME: ____ GAL
(2) Do not proceed further.
A.2.2 If the answer is no, calculate the total aboveground oil storage capacity of tanks without adequate secondary containment. If all aboveground oil storage tanks or groups of aboveground oil storage tanks at the facility have adequate secondary containment, ENTER “0” (zero).
A.2.3 Calculate the capacity of the largest single aboveground oil storage tank within an adequate secondary containment area or the combined capacity of a group of aboveground oil storage tanks permanently manifolded together, whichever is greater, PLUS THE VOLUME FROM QUESTION A.2.2.
FINAL WORST CASE VOLUME:
Part B of this worksheet is to be completed by the owner or operator of an SPCC-regulated oil production facility if the facility meets the criteria presented in appendix C to this part, or if it is determined by the RA that the facility could cause substantial harm. A production facility consists of all wells (producing and exploratory) and related equipment in a single geographical oil or gas field operated by a single operator.
B.1.1 For facilities containing only one aboveground oil storage tank, the worst case discharge planning volume equals the capacity of the aboveground oil storage tank plus the production volume of the well with the highest output at the facility. If adequate secondary containment (sufficiently large to contain the capacity of the aboveground oil storage tank plus sufficient freeboard to allow for precipitation) exists for the storage tank, multiply the capacity of the tank by 0.8.
B.1.2 For facilities with production wells producing by pumping, if the rate of the well with the highest output is known and the number of days the facility is unattended can be predicted, then the production volume is equal to the pumping rate of the well multiplied by the greatest number of days the facility is unattended.
B.1.3 If the pumping rate of the well with the highest output is estimated or the maximum number of days the facility is unattended is estimated, then the production volume is determined from the pumping rate of the well multiplied by 1.5 times the greatest number of days that the facility has been or is expected to be unattended.
B.1.4 Attachment D-1 to this appendix provides methods for calculating the production volume for exploratory wells and production wells producing under pressure.
(1) FINAL WORST CASE VOLUME: ____ GAL
(2) Do not proceed further.
Are all aboveground oil storage tanks or groups of aboveground oil storage tanks at the facility without adequate secondary containment?
B.2.1 If the answer is yes, the final worst case volume equals the total aboveground oil storage capacity without adequate secondary containment plus the production volume of the well with the highest output at the facility.
(1) For facilities with production wells producing by pumping, if the rate of the well with the highest output is known and the number of days the facility is unattended can be predicted, then the production volume is equal to the pumping rate of the well multiplied by the greatest number of days the facility is unattended.
(2) If the pumping rate of the well with the highest output is estimated or the maximum number of days the facility is unattended is estimated, then the production volume is determined from the pumping rate of the well multiplied by 1.5 times the greatest number of days that the facility has been or is expected to be unattended.
(3) Attachment D-1 to this appendix provides methods for calculating the production volumes for exploratory wells and production wells producing under pressure.
(A) FINAL WORST CASE VOLUME: ____ GAL
(B) Do not proceed further.
B.2.2 If the answer is no, calculate the total aboveground oil storage capacity of tanks without adequate secondary containment. If all aboveground oil storage tanks or groups of aboveground oil storage tanks at the facility have adequate secondary containment, ENTER “0” (zero).
B.2.3 Calculate the capacity of the largest single aboveground oil storage tank within an adequate secondary containment area or the combined capacity of a group of aboveground oil storage tanks permanently manifolded together, whichever is greater, plus the production volume of the well with the highest output, PLUS THE VOLUME FROM QUESTION B.2.2. Attachment D-1 provides methods for calculating the production volumes for exploratory wells and production wells producing under pressure.
(1) FINAL WORST CASE VOLUME:
(2) Do not proceed further.
The owner or operator of a production facility with exploratory wells or production wells producing under pressure shall compare the well rate of the highest output well (rate of well), in barrels per day, to the ability of response equipment and personnel to recover the volume of oil that could be discharged (rate of recovery), in barrels per day. The result of this comparison will determine the method used to calculate the production volume for the production facility. This production volume is to be used to calculate the worst case discharge planning volume in part B of this appendix.
2.1 Method A
If the well rate would overwhelm the response efforts (i.e., rate of well/rate of recovery ≥1), then the production volume would be the 30-day forecasted well rate for a well 10,000 feet deep or less, or the 45-day forecasted well rate for a well deeper than 10,000 feet.
(1) For wells 10,000 feet deep or less:
(2) For wells deeper than 10,000 feet:
2.2 Method B
2.2.1 If the rate of recovery would be greater than the well rate (i.e., rate of well/rate of recovery
2.2.2 The first term represents the volume of the oil discharged from the well between the time of the blowout and the time the response resources are on scene and recovering oil (discharge volume
2.2.3 The second term represents the volume of oil discharged from the well after the response resources begin operating until the discharge is stopped, adjusted for the recovery rate of the response resources (discharge volume
(1) For wells 10,000 feet deep or less:
(2) For wells deeper than 10,000 feet:
3.1 A facility consists of two production wells producing under pressure, which are both less than 10,000 feet deep. The well rate of well A is 5 barrels per day, and the well rate of well B is 10 barrels per day. The facility is unattended for a maximum of 7 days. The facility operator estimates that it will take 2 days to have response equipment and personnel on scene and responding to a blowout, and that the projected rate of recovery will be 20 barrels per day.
(1) First, the facility operator determines that the highest output well is well B. The facility operator calculates the ratio of the rate of well to the rate of recovery:
(2) The first term of the equation is:
(3) The second term of the equation is:
(4) Therefore, the production volume is:
3.2 If the recovery rate was 5 barrels per day, the ratio of rate of well to rate of recovery would be 2, so the facility operator would use Method A. The production volume would have been:
Appendix E to Part 112 – Determination and Evaluation of Required Response Resources for Facility Response Plans
1.1 The purpose of this appendix is to describe the procedures to identify response resources to meet the requirements of § 112.20. To identify response resources to meet the facility response plan requirements of 40 CFR 112.20(h), owners or operators shall follow this appendix or, where not appropriate, shall clearly demonstrate in the response plan why use of this appendix is not appropriate at the facility and make comparable arrangements for response resources.
1.2 Definitions.
1.2.1 Animal fat means a non-petroleum oil, fat, or grease of animal, fish, or marine mammal origin. Animal fats are further classified based on specific gravity as follows:
(1) Group A – specific gravity less than 0.8.
(2) Group B – specific gravity equal to or greater than 0.8 and less than 1.0.
(3) Group C – specific gravity equal to or greater than 1.0.
1.2.2 Nearshore is an operating area defined as extending seaward 12 miles from the boundary lines defined in 46 CFR part 7, except in the Gulf of Mexico. In the Gulf of Mexico, it means the area extending 12 miles from the line of demarcation (COLREG lines) defined in 49 CFR 80.740 and 80.850.
1.2.3 Non-persistent oils or Group 1 oils include:
(1) A petroleum-based oil that, at the time of shipment, consists of hydrocarbon fractions:
(A) At least 50 percent of which by volume, distill at a temperature of 340 degrees C (645 degrees F); and
(B) At least 95 percent of which by volume, distill at a temperature of 370 degrees C (700 degrees F); and
(2) A non-petroleum oil, other than an animal fat or vegetable oil, with a specific gravity less than 0.8.
1.2.4 Non-petroleum oil means oil of any kind that is not petroleum-based, including but not limited to: fats, oils, and greases of animal, fish, or marine mammal origin; and vegetable oils, including oils from seeds, nuts, fruits, and kernels.
1.2.5 Ocean means the nearshore area.
1.2.6 Operating area means Rivers and Canals, Inland, Nearshore, and Great Lakes geographic location(s) in which a facility is handling, storing, or transporting oil.
1.2.7 Operating environment means Rivers and Canals, Inland, Great Lakes, or Ocean. These terms are used to define the conditions in which response equipment is designed to function.
1.2.8 Persistent oils include:
(1) A petroleum-based oil that does not meet the distillation criteria for a non-persistent oil. Persistent oils are further classified based on specific gravity as follows:
(A) Group 2 – specific gravity less than 0.85;
(B) Group 3 – specific gravity equal to or greater than 0.85 and less than 0.95;
(C) Group 4 – specific gravity equal to or greater than 0.95 and less than 1.0; or
(D) Group 5 – specific gravity equal to or greater than 1.0.
(2) A non-petroleum oil, other than an animal fat or vegetable oil, with a specific gravity of 0.8 or greater. These oils are further classified based on specific gravity as follows:
(A) Group 2 – specific gravity equal to or greater than 0.8 and less than 0.85;
(B) Group 3 – specific gravity equal to or greater than 0.85 and less than 0.95;
(C) Group 4 – specific gravity equal to or greater than 0.95 and less than 1.0; or
(D) Group 5 – specific gravity equal to or greater than 1.0.
1.2.9 Vegetable oil means a non-petroleum oil or fat of vegetable origin, including but not limited to oils and fats derived from plant seeds, nuts, fruits, and kernels. Vegetable oils are further classified based on specific gravity as follows:
(1) Group A – specific gravity less than 0.8.
(2) Group B – specific gravity equal to or greater than 0.8 and less than 1.0.
(3) Group C – specific gravity equal to or greater than 1.0.
1.2.10 Other definitions are included in § 112.2, section 1.1 of appendix C, and section 3.0 of appendix F.
2.1 All equipment identified in a response plan must be designed to operate in the conditions expected in the facility’s geographic area (i.e., operating environment). These conditions vary widely based on location and season. Therefore, it is difficult to identify a single stockpile of response equipment that will function effectively in each geographic location (i.e., operating area).
2.2 Facilities handling, storing, or transporting oil in more than one operating environment as indicated in Table 1 of this appendix must identify equipment capable of successfully functioning in each operating environment.
2.3 When identifying equipment for the response plan (based on the use of this appendix), a facility owner or operator must consider the inherent limitations of the operability of equipment components and response systems. The criteria in Table 1 of this appendix shall be used to evaluate the operability in a given environment. These criteria reflect the general conditions in certain operating environments.
2.3.1 The Regional Administrator may require documentation that the boom identified in a facility response plan meets the criteria in Table 1 of this appendix. Absent acceptable documentation, the Regional Administrator may require that the boom be tested to demonstrate that it meets the criteria in Table 1 of this appendix. Testing must be in accordance with ASTM F 715, ASTM F 989, or other tests approved by EPA as deemed appropriate (see appendix E to this part, section 13, for general availability of documents).
2.4 Table 1 of this appendix lists criteria for oil recovery devices and boom. All other equipment necessary to sustain or support response operations in an operating environment must be designed to function in the same conditions. For example, boats that deploy or support skimmers or boom must be capable of being safely operated in the significant wave heights listed for the applicable operating environment.
2.5 A facility owner or operator shall refer to the applicable Area Contingency Plan (ACP), where available, to determine if ice, debris, and weather-related visibility are significant factors to evaluate the operability of equipment. The ACP may also identify the average temperature ranges expected in the facility’s operating area. All equipment identified in a response plan must be designed to operate within those conditions or ranges.
2.6 This appendix provides information on response resource mobilization and response times. The distance of the facility from the storage location of the response resources must be used to determine whether the resources can arrive on-scene within the stated time. A facility owner or operator shall include the time for notification, mobilization, and travel of resources identified to meet the medium and Tier 1 worst case discharge requirements identified in sections 4.3 and 9.3 of this appendix (for medium discharges) and section 5.3 of this appendix (for worst case discharges). The facility owner or operator must plan for notification and mobilization of Tier 2 and 3 response resources as necessary to meet the requirements for arrival on-scene in accordance with section 5.3 of this appendix. An on-water speed of 5 knots and a land speed of 35 miles per hour is assumed, unless the facility owner or operator can demonstrate otherwise.
2.7 In identifying equipment, the facility owner or operator shall list the storage location, quantity, and manufacturer’s make and model. For oil recovery devices, the effective daily recovery capacity, as determined using section 6 of this appendix, must be included. For boom, the overall boom height (draft and freeboard) shall be included. A facility owner or operator is responsible for ensuring that the identified boom has compatible connectors.
3.1 A facility owner or operator shall identify sufficient response resources available, by contract or other approved means as described in § 112.2, to respond to a small discharge. A small discharge is defined as any discharge volume less than or equal to 2,100 gallons, but not to exceed the calculated worst case discharge. The equipment must be designed to function in the operating environment at the point of expected use.
3.2 Complexes that are regulated by EPA and the United States Coast Guard (USCG) must also consider planning quantities for the transportation-related transfer portion of the facility.
3.2.1 Petroleum oils. The USCG planning level that corresponds to EPA’s “small discharge” is termed “the average most probable discharge.” A USCG rule found at 33 CFR 154.1020 defines “the average most probable discharge” as the lesser of 50 barrels (2,100 gallons) or 1 percent of the volume of the worst case discharge. Owners or operators of complexes that handle, store, or transport petroleum oils must compare oil discharge volumes for a small discharge and an average most probable discharge, and plan for whichever quantity is greater.
3.2.2 Non-petroleum oils other than animal fats and vegetable oils. Owners or operators of complexes that handle, store, or transport non-petroleum oils other than animal fats and vegetable oils must plan for oil discharge volumes for a small discharge. There is no USCG planning level that directly corresponds to EPA’s “small discharge.” However, the USCG (at 33 CFR 154.545) has requirements to identify equipment to contain oil resulting from an operational discharge.
3.3 The response resources shall, as appropriate, include:
3.3.1 One thousand feet of containment boom (or, for complexes with marine transfer components, 1,000 feet of containment boom or two times the length of the largest vessel that regularly conducts oil transfers to or from the facility, whichever is greater), and a means of deploying it within 1 hour of the discovery of a discharge;
3.3.2 Oil recovery devices with an effective daily recovery capacity equal to the amount of oil discharged in a small discharge or greater which is available at the facility within 2 hours of the detection of an oil discharge; and
3.3.3 Oil storage capacity for recovered oily material indicated in section 12.2 of this appendix.
4.1 A facility owner or operator shall identify sufficient response resources available, by contract or other approved means as described in § 112.2, to respond to a medium discharge of oil for that facility. This will require response resources capable of containing and collecting up to 36,000 gallons of oil or 10 percent of the worst case discharge, whichever is less. All equipment identified must be designed to operate in the applicable operating environment specified in Table 1 of this appendix.
4.2 Complexes that are regulated by EPA and the USCG must also consider planning quantities for the transportation-related transfer portion of the facility.
4.2.1 Petroleum oils. The USCG planning level that corresponds to EPA’s “medium discharge” is termed “the maximum most probable discharge.” The USCG rule found at 33 CFR part 154 defines “the maximum most probable discharge” as a discharge of 1,200 barrels (50,400 gallons) or 10 percent of the worst case discharge, whichever is less. Owners or operators of complexes that handle, store, or transport petroleum oils must compare calculated discharge volumes for a medium discharge and a maximum most probable discharge, and plan for whichever quantity is greater.
4.2.2 Non-petroleum oils other than animal fats and vegetable oils. Owners or operators of complexes that handle, store, or transport non-petroleum oils other than animal fats and vegetable oils must plan for oil discharge volumes for a medium discharge. For non-petroleum oils, there is no USCG planning level that directly corresponds to EPA’s “medium discharge.”
4.3 Oil recovery devices identified to meet the applicable medium discharge volume planning criteria must be located such that they are capable of arriving on-scene within 6 hours in higher volume port areas and the Great Lakes and within 12 hours in all other areas. Higher volume port areas and Great Lakes areas are defined in section 1.1 of appendix C to this part.
4.4 Because rapid control, containment, and removal of oil are critical to reduce discharge impact, the owner or operator must determine response resources using an effective daily recovery capacity for oil recovery devices equal to 50 percent of the planning volume applicable for the facility as determined in section 4.1 of this appendix. The effective daily recovery capacity for oil recovery devices identified in the plan must be determined using the criteria in section 6 of this appendix.
4.5 In addition to oil recovery capacity, the plan shall, as appropriate, identify sufficient quantity of containment boom available, by contract or other approved means as described in § 112.2, to arrive within the required response times for oil collection and containment and for protection of fish and wildlife and sensitive environments. For further description of fish and wildlife and sensitive environments, see Appendices I, II, and III to DOC/NOAA’s “Guidance for Facility and Vessel Response Plans: Fish and Wildlife and Sensitive Environments” (see appendix E to this part, section 13, for availability) and the applicable ACP. Although 40 CFR part 112 does not set required quantities of boom for oil collection and containment, the response plan shall identify and ensure, by contract or other approved means as described in § 112.2, the availability of the quantity of boom identified in the plan for this purpose.
4.6 The plan must indicate the availability of temporary storage capacity to meet section 12.2 of this appendix. If available storage capacity is insufficient to meet this level, then the effective daily recovery capacity must be derated (downgraded) to the limits of the available storage capacity.
4.7 The following is an example of a medium discharge volume planning calculation for equipment identification in a higher volume port area: The facility’s largest aboveground storage tank volume is 840,000 gallons. Ten percent of this capacity is 84,000 gallons. Because 10 percent of the facility’s largest tank, or 84,000 gallons, is greater than 36,000 gallons, 36,000 gallons is used as the planning volume. The effective daily recovery capacity is 50 percent of the planning volume, or 18,000 gallons per day. The ability of oil recovery devices to meet this capacity must be calculated using the procedures in section 6 of this appendix. Temporary storage capacity available on-scene must equal twice the daily recovery capacity as indicated in section 12.2 of this appendix, or 36,000 gallons per day. This is the information the facility owner or operator must use to identify and ensure the availability of the required response resources, by contract or other approved means as described in § 112.2. The facility owner shall also identify how much boom is available for use.
5.1 A facility owner or operator shall identify and ensure the availability of, by contract or other approved means as described in § 112.2, sufficient response resources to respond to the worst case discharge of oil to the maximum extent practicable. Sections 7 and 10 of this appendix describe the method to determine the necessary response resources. Worksheets are provided as Attachments E-1 and E-2 at the end of this appendix to simplify the procedures involved in calculating the planning volume for response resources for the worst case discharge.
5.2 Complexes that are regulated by EPA and the USCG must also consider planning for the worst case discharge at the transportation-related portion of the facility. The USCG requires that transportation-related facility owners or operators use a different calculation for the worst case discharge in the revisions to 33 CFR part 154. Owners or operators of complex facilities that are regulated by EPA and the USCG must compare both calculations of worst case discharge derived by EPA and the USCG and plan for whichever volume is greater.
5.3 Oil discharge response resources identified in the response plan and available, by contract or other approved means as described in § 112.2, to meet the applicable worst case discharge planning volume must be located such that they are capable of arriving at the scene of a discharge within the times specified for the applicable response tier listed as follows
| Tier 1 (in hours) | Tier 2 (in hours) | Tier 3 (in hours) | |
|---|---|---|---|
| Higher volume port areas | 6 | 30 | 54 |
| Great Lakes | 12 | 36 | 60 |
| All other river and canal, inland, and nearshore areas | 12 | 36 | 60 |
The three levels of response tiers apply to the amount of time in which facility owners or operators must plan for response resources to arrive at the scene of a discharge to respond to the worst case discharge planning volume. For example, at a worst case discharge in an inland area, the first tier of response resources (i.e., that amount of on-water and shoreline cleanup capacity necessary to respond to the fraction of the worst case discharge as indicated through the series of steps described in sections 7.2 and 7.3 or sections 10.2 and 10.3 of this appendix) would arrive at the scene of the discharge within 12 hours; the second tier of response resources would arrive within 36 hours; and the third tier of response resources would arrive within 60 hours.
5.4 The effective daily recovery capacity for oil recovery devices identified in the response plan must be determined using the criteria in section 6 of this appendix. A facility owner or operator shall identify the storage locations of all response resources used for each tier. The owner or operator of a facility whose required daily recovery capacity exceeds the applicable contracting caps in Table 5 of this appendix shall, as appropriate, identify sources of additional equipment, their location, and the arrangements made to obtain this equipment during a response. The owner or operator of a facility whose calculated planning volume exceeds the applicable contracting caps in Table 5 of this appendix shall, as appropriate, identify sources of additional equipment equal to twice the cap listed in Tier 3 or the amount necessary to reach the calculated planning volume, whichever is lower. The resources identified above the cap shall be capable of arriving on-scene not later than the Tier 3 response times in section 5.3 of this appendix. No contract is required. While general listings of available response equipment may be used to identify additional sources (i.e., “public” resources vs. “private” resources), the response plan shall identify the specific sources, locations, and quantities of equipment that a facility owner or operator has considered in his or her planning. When listing USCG-classified oil spill removal organization(s) that have sufficient removal capacity to recover the volume above the response capacity cap for the specific facility, as specified in Table 5 of this appendix, it is not necessary to list specific quantities of equipment.
5.5 A facility owner or operator shall identify the availability of temporary storage capacity to meet section 12.2 of this appendix. If available storage capacity is insufficient, then the effective daily recovery capacity must be derated (downgraded) to the limits of the available storage capacity.
5.6 When selecting response resources necessary to meet the response plan requirements, the facility owner or operator shall, as appropriate, ensure that a portion of those resources is capable of being used in close-to-shore response activities in shallow water. For any EPA-regulated facility that is required to plan for response in shallow water, at least 20 percent of the on-water response equipment identified for the applicable operating area shall, as appropriate, be capable of operating in water of 6 feet or less depth.
5.7 In addition to oil spill recovery devices, a facility owner or operator shall identify sufficient quantities of boom that are available, by contract or other approved means as described in § 112.2, to arrive on-scene within the specified response times for oil containment and collection. The specific quantity of boom required for collection and containment will depend on the facility-specific information and response strategies employed. A facility owner or operator shall, as appropriate, also identify sufficient quantities of oil containment boom to protect fish and wildlife and sensitive environments. For further description of fish and wildlife and sensitive environments, see Appendices I, II, and III to DOC/NOAA’s “Guidance for Facility and Vessel Response Plans: Fish and Wildlife and Sensitive Environments” (see appendix E to this part, section 13, for availability), and the applicable ACP. Refer to this guidance document for the number of days and geographic areas (i.e., operating environments) specified in Table 2 and Table 6 of this appendix.
5.8 A facility owner or operator shall also identify, by contract or other approved means as described in § 112.2, the availability of an oil spill removal organization(s) (as described in § 112.2) capable of responding to a shoreline cleanup operation involving the calculated volume of oil and emulsified oil that might impact the affected shoreline. The volume of oil that shall, as appropriate, be planned for is calculated through the application of factors contained in Tables 2, 3, 6, and 7 of this appendix. The volume calculated from these tables is intended to assist the facility owner or operator to identify an oil spill removal organization with sufficient resources and expertise.
6.1 Oil recovery devices identified by a facility owner or operator must be identified by the manufacturer, model, and effective daily recovery capacity. These capacities must be used to determine whether there is sufficient capacity to meet the applicable planning criteria for a small discharge, a medium discharge, and a worst case discharge to the maximum extent practicable.
6.2 To determine the effective daily recovery capacity of oil recovery devices, the formula listed in section 6.2.1 of this appendix shall be used. This formula considers potential limitations due to available daylight, weather, sea state, and percentage of emulsified oil in the recovered material. The RA may assign a lower efficiency factor to equipment listed in a response plan if it is determined that such a reduction is warranted.
6.2.1 The following formula shall be used to calculate the effective daily recovery capacity:
6.2.2 For those devices in which the pump limits the throughput of liquid, throughput rate shall be calculated using the pump capacity.
6.2.3 For belt or moptype devices, the throughput rate shall be calculated using the speed of the belt or mop through the device, assumed thickness of oil adhering to or collected by the device, and surface area of the belt or mop. For purposes of this calculation, the assumed thickness of oil will be
6.2.4 Facility owners or operators that include oil recovery devices whose throughput is not measurable using a pump capacity or belt/mop speed may provide information to support an alternative method of calculation. This information must be submitted following the procedures in section 6.3.2 of this appendix.
6.3 As an alternative to section 6.2 of this appendix, a facility owner or operator may submit adequate evidence that a different effective daily recovery capacity should be applied for a specific oil recovery device. Adequate evidence is actual verified performance data in discharge conditions or tests using American Society of Testing and Materials (ASTM) Standard F 631-99, F 808-83 (1999), or an equivalent test approved by EPA as deemed appropriate (see Appendix E to this part, section 13, for general availability of documents).
6.3.1 The following formula must be used to calculate the effective daily recovery capacity under this alternative:
6.3.2 A facility owner or operator submitting a response plan shall provide data that supports the effective daily recovery capacities for the oil recovery devices listed. The following is an example of these calculations:
(1) A weir skimmer identified in a response plan has a manufacturer’s rated throughput at the pump of 267 gallons per minute (gpm).
(2) After testing using ASTM procedures, the skimmer’s oil recovery rate is determined to be 220 gpm. The facility owner or operator identifies sufficient resources available to support operations for 12 hours per day.
(3) The facility owner or operator will be able to use the higher capacity if sufficient temporary oil storage capacity is available. Determination of alternative efficiency factors under section 6.2 of this appendix or the acceptability of an alternative effective daily recovery capacity under section 6.3 of this appendix will be made by the Regional Administrator as deemed appropriate.
7.1 A facility owner or operator shall plan for a response to the facility’s worst case discharge. The planning for on-water oil recovery must take into account a loss of some oil to the environment due to evaporative and natural dissipation, potential increases in volume due to emulsification, and the potential for deposition of oil on the shoreline. The procedures for non-petroleum oils other than animal fats and vegetable oils are discussed in section 7.7 of this appendix.
7.2 The following procedures must be used by a facility owner or operator in determining the required on-water oil recovery capacity:
7.2.1 The following must be determined: the worst case discharge volume of oil in the facility; the appropriate group(s) for the types of oil handled, stored, or transported at the facility [persistent (Groups 2, 3, 4, 5) or non-persistent (Group 1)]; and the facility’s specific operating area. See sections 1.2.3 and 1.2.8 of this appendix for the definitions of non-persistent and persistent oils, respectively. Facilities that handle, store, or transport oil from different oil groups must calculate each group separately, unless the oil group constitutes 10 percent or less by volume of the facility’s total oil storage capacity. This information is to be used with Table 2 of this appendix to determine the percentages of the total volume to be used for removal capacity planning. Table 2 of this appendix divides the volume into three categories: oil lost to the environment; oil deposited on the shoreline; and oil available for on-water recovery.
7.2.2 The on-water oil recovery volume shall, as appropriate, be adjusted using the appropriate emulsification factor found in Table 3 of this appendix. Facilities that handle, store, or transport oil from different petroleum groups must compare the on-water recovery volume for each oil group (unless the oil group constitutes 10 percent or less by volume of the facility’s total storage capacity) and use the calculation that results in the largest on-water oil recovery volume to plan for the amount of response resources for a worst case discharge.
7.2.3 The adjusted volume is multiplied by the on-water oil recovery resource mobilization factor found in Table 4 of this appendix from the appropriate operating area and response tier to determine the total on-water oil recovery capacity in barrels per day that must be identified or contracted to arrive on-scene within the applicable time for each response tier. Three tiers are specified. For higher volume port areas, the contracted tiers of resources must be located such that they are capable of arriving on-scene within 6 hours for Tier 1, 30 hours for Tier 2, and 54 hours for Tier 3 of the discovery of an oil discharge. For all other rivers and canals, inland, nearshore areas, and the Great Lakes, these tiers are 12, 36, and 60 hours.
7.2.4 The resulting on-water oil recovery capacity in barrels per day for each tier is used to identify response resources necessary to sustain operations in the applicable operating area. The equipment shall be capable of sustaining operations for the time period specified in Table 2 of this appendix. The facility owner or operator shall identify and ensure the availability, by contract or other approved means as described in § 112.2, of sufficient oil spill recovery devices to provide the effective daily oil recovery capacity required. If the required capacity exceeds the applicable cap specified in Table 5 of this appendix, then a facility owner or operator shall ensure, by contract or other approved means as described in § 112.2, only for the quantity of resources required to meet the cap, but shall identify sources of additional resources as indicated in section 5.4 of this appendix. The owner or operator of a facility whose planning volume exceeded the cap in 1993 must make arrangements to identify and ensure the availability, by contract or other approved means as described in § 112.2, for additional capacity to be under contract by 1998 or 2003, as appropriate. For a facility that handles multiple groups of oil, the required effective daily recovery capacity for each oil group is calculated before applying the cap. The oil group calculation resulting in the largest on-water recovery volume must be used to plan for the amount of response resources for a worst case discharge, unless the oil group comprises 10 percent or less by volume of the facility’s total oil storage capacity.
7.3 The procedures discussed in sections 7.3.1-7.3.3 of this appendix must be used to calculate the planning volume for identifying shoreline cleanup capacity (for Group 1 through Group 4 oils).
7.3.1 The following must be determined: the worst case discharge volume of oil for the facility; the appropriate group(s) for the types of oil handled, stored, or transported at the facility [persistent (Groups 2, 3, or 4) or non-persistent (Group 1)]; and the geographic area(s) in which the facility operates (i.e., operating areas). For a facility handling, storing, or transporting oil from different groups, each group must be calculated separately. Using this information, Table 2 of this appendix must be used to determine the percentages of the total volume to be used for shoreline cleanup resource planning.
7.3.2 The shoreline cleanup planning volume must be adjusted to reflect an emulsification factor using the same procedure as described in section 7.2.2 of this appendix.
7.3.3 The resulting volume shall be used to identify an oil spill removal organization with the appropriate shoreline cleanup capability.
7.4 A response plan must identify response resources with fire fighting capability. The owner or operator of a facility that handles, stores, or transports Group 1 through Group 4 oils that does not have adequate fire fighting resources located at the facility or that cannot rely on sufficient local fire fighting resources must identify adequate fire fighting resources. The facility owner or operator shall ensure, by contract or other approved means as described in § 112.2, the availability of these resources. The response plan must also identify an individual located at the facility to work with the fire department for Group 1 through Group 4 oil fires. This individual shall also verify that sufficient well-trained fire fighting resources are available within a reasonable response time to a worst case scenario. The individual may be the qualified individual identified in the response plan or another appropriate individual located at the facility.
7.5 The following is an example of the procedure described above in sections 7.2 and 7.3 of this appendix: A facility with a 270,000 barrel (11.3 million gallons) capacity for #6 oil (specific gravity 0.96) is located in a higher volume port area. The facility is on a peninsula and has docks on both the ocean and bay sides. The facility has four aboveground oil storage tanks with a combined total capacity of 80,000 barrels (3.36 million gallons) and no secondary containment. The remaining facility tanks are inside secondary containment structures. The largest aboveground oil storage tank (90,000 barrels or 3.78 million gallons) has its own secondary containment. Two 50,000 barrel (2.1 million gallon) tanks (that are not connected by a manifold) are within a common secondary containment tank area, which is capable of holding 100,000 barrels (4.2 million gallons) plus sufficient freeboard.
7.5.1 The worst case discharge for the facility is calculated by adding the capacity of all aboveground oil storage tanks without secondary containment (80,000 barrels) plus the capacity of the largest aboveground oil storage tank inside secondary containment. The resulting worst case discharge volume is 170,000 barrels or 7.14 million gallons.
7.5.2 Because the requirements for Tiers 1, 2, and 3 for inland and nearshore exceed the caps identified in Table 5 of this appendix, the facility owner will contract for a response to 10,000 barrels per day (bpd) for Tier 1, 20,000 bpd for Tier 2, and 40,000 bpd for Tier 3. Resources for the remaining 7,850 bpd for Tier 1, 9,750 bpd for Tier 2, and 7,600 bpd for Tier 3 shall be identified but need not be contracted for in advance. The facility owner or operator shall, as appropriate, also identify or contract for quantities of boom identified in their response plan for the protection of fish and wildlife and sensitive environments within the area potentially impacted by a worst case discharge from the facility. For further description of fish and wildlife and sensitive environments, see Appendices I, II, and III to DOC/NOAA’s “Guidance for Facility and Vessel Response Plans: Fish and Wildlife and Sensitive Environments,” (see appendix E to this part, section 13, for availability) and the applicable ACP. Attachment C-III to Appendix C provides a method for calculating a planning distance to fish and wildlife and sensitive environments and public drinking water intakes that may be impacted in the event of a worst case discharge.
7.6 The procedures discussed in sections 7.6.1-7.6.3 of this appendix must be used to determine appropriate response resources for facilities with Group 5 oils.
7.6.1 The owner or operator of a facility that handles, stores, or transports Group 5 oils shall, as appropriate, identify the response resources available by contract or other approved means, as described in § 112.2. The equipment identified in a response plan shall, as appropriate, include:
(1) Sonar, sampling equipment, or other methods for locating the oil on the bottom or suspended in the water column;
(2) Containment boom, sorbent boom, silt curtains, or other methods for containing the oil that may remain floating on the surface or to reduce spreading on the bottom;
(3) Dredges, pumps, or other equipment necessary to recover oil from the bottom and shoreline;
(4) Equipment necessary to assess the impact of such discharges; and
(5) Other appropriate equipment necessary to respond to a discharge involving the type of oil handled, stored,, or transported.
7.6.2 Response resources identified in a response plan for a facility that handles, stores, or transports Group 5 oils under section 7.6.1 of this appendix shall be capable of being deployed (on site) within 24 hours of discovery of a discharge to the area where the facility is operating.
7.6.3 A response plan must identify response resources with fire fighting capability. The owner or operator of a facility that handles, stores, or transports Group 5 oils that does not have adequate fire fighting resources located at the facility or that cannot rely on sufficient local fire fighting resources must identify adequate fire fighting resources. The facility owner or operator shall ensure, by contract or other approved means as described in § 112.2, the availability of these resources. The response plan shall also identify an individual located at the facility to work with the fire department for Group 5 oil fires. This individual shall also verify that sufficient well-trained fire fighting resources are available within a reasonable response time to respond to a worst case discharge. The individual may be the qualified individual identified in the response plan or another appropriate individual located at the facility.
7.7 Non-petroleum oils other than animal fats and vegetable oils. The procedures described in sections 7.7.1 through 7.7.5 of this appendix must be used to determine appropriate response plan development and evaluation criteria for facilities that handle, store, or transport non-petroleum oils other than animal fats and vegetable oils. Refer to section 11 of this appendix for information on the limitations on the use of chemical agents for inland and nearshore areas.
7.7.1 An owner or operator of a facility that handles, stores, or transports non-petroleum oils other than animal fats and vegetable oils must provide information in his or her plan that identifies:
(1) Procedures and strategies for responding to a worst case discharge to the maximum extent practicable; and
(2) Sources of the equipment and supplies necessary to locate, recover, and mitigate such a discharge.
7.7.2 An owner or operator of a facility that handles, stores, or transports non-petroleum oils other than animal fats and vegetable oils must ensure that any equipment identified in a response plan is capable of operating in the conditions expected in the geographic area(s) (i.e., operating environments) in which the facility operates using the criteria in Table 1 of this appendix. When evaluating the operability of equipment, the facility owner or operator must consider limitations that are identified in the appropriate ACPs, including:
(1) Ice conditions;
(2) Debris;
(3) Temperature ranges; and
(4) Weather-related visibility.
7.7.3 The owner or operator of a facility that handles, stores, or transports non-petroleum oils other than animal fats and vegetable oils must identify the response resources that are available by contract or other approved means, as described in § 112.2. The equipment described in the response plan shall, as appropriate, include:
(1) Containment boom, sorbent boom, or other methods for containing oil floating on the surface or to protect shorelines from impact;
(2) Oil recovery devices appropriate for the type of non-petroleum oil carried; and
(3) Other appropriate equipment necessary to respond to a discharge involving the type of oil carried.
7.7.4 Response resources identified in a response plan according to section 7.7.3 of this appendix must be capable of commencing an effective on-scene response within the applicable tier response times in section 5.3 of this appendix.
7.7.5 A response plan must identify response resources with fire fighting capability. The owner or operator of a facility that handles, stores, or transports non-petroleum oils other than animal fats and vegetable oils that does not have adequate fire fighting resources located at the facility or that cannot rely on sufficient local fire fighting resources must identify adequate fire fighting resources. The owner or operator shall ensure, by contract or other approved means as described in § 112.2, the availability of these resources. The response plan must also identify an individual located at the facility to work with the fire department for fires of these oils. This individual shall also verify that sufficient well-trained fire fighting resources are available within a reasonable response time to a worst case scenario. The individual may be the qualified individual identified in the response plan or another appropriate individual located at the facility.
8.1 A facility owner or operator shall identify sufficient response resources available, by contract or other approved means as described in § 112.2, to respond to a small discharge of animal fats or vegetable oils. A small discharge is defined as any discharge volume less than or equal to 2,100 gallons, but not to exceed the calculated worst case discharge. The equipment must be designed to function in the operating environment at the point of expected use.
8.2 Complexes that are regulated by EPA and the USCG must also consider planning quantities for the marine transportation-related portion of the facility.
8.2.1 The USCG planning level that corresponds to EPA’s “small discharge” is termed “the average most probable discharge.” A USCG rule found at 33 CFR 154.1020 defines “the average most probable discharge” as the lesser of 50 barrels (2,100 gallons) or 1 percent of the volume of the worst case discharge. Owners or operators of complexes that handle, store, or transport animal fats and vegetable oils must compare oil discharge volumes for a small discharge and an average most probable discharge, and plan for whichever quantity is greater.
8.3 The response resources shall, as appropriate, include:
8.3.1 One thousand feet of containment boom (or, for complexes with marine transfer components, 1,000 feet of containment boom or two times the length of the largest vessel that regularly conducts oil transfers to or from the facility, whichever is greater), and a means of deploying it within 1 hour of the discovery of a discharge;
8.3.2 Oil recovery devices with an effective daily recovery capacity equal to the amount of oil discharged in a small discharge or greater which is available at the facility within 2 hours of the detection of a discharge; and
8.3.3 Oil storage capacity for recovered oily material indicated in section 12.2 of this appendix.
9.1 A facility owner or operator shall identify sufficient response resources available, by contract or other approved means as described in § 112.2, to respond to a medium discharge of animal fats or vegetable oils for that facility. This will require response resources capable of containing and collecting up to 36,000 gallons of oil or 10 percent of the worst case discharge, whichever is less. All equipment identified must be designed to operate in the applicable operating environment specified in Table 1 of this appendix.
9.2 Complexes that are regulated by EPA and the USCG must also consider planning quantities for the transportation-related transfer portion of the facility. Owners or operators of complexes that handle, store, or transport animal fats or vegetable oils must plan for oil discharge volumes for a medium discharge. For non-petroleum oils, there is no USCG planning level that directly corresponds to EPA’s “medium discharge.” Although the USCG does not have planning requirements for medium discharges, they do have requirements (at 33 CFR 154.545) to identify equipment to contain oil resulting from an operational discharge.
9.3 Oil recovery devices identified to meet the applicable medium discharge volume planning criteria must be located such that they are capable of arriving on-scene within 6 hours in higher volume port areas and the Great Lakes and within 12 hours in all other areas. Higher volume port areas and Great Lakes areas are defined in section 1.1 of appendix C to this part.
9.4 Because rapid control, containment, and removal of oil are critical to reduce discharge impact, the owner or operator must determine response resources using an effective daily recovery capacity for oil recovery devices equal to 50 percent of the planning volume applicable for the facility as determined in section 9.1 of this appendix. The effective daily recovery capacity for oil recovery devices identified in the plan must be determined using the criteria in section 6 of this appendix.
9.5 In addition to oil recovery capacity, the plan shall, as appropriate, identify sufficient quantity of containment boom available, by contract or other approved means as described in § 112.2, to arrive within the required response times for oil collection and containment and for protection of fish and wildlife and sensitive environments. For further description of fish and wildlife and sensitive environments, see Appendices I, II, and III to DOC/NOAA’s “Guidance for Facility and Vessel Response Plans: Fish and Wildlife and Sensitive Environments” (59 FR 14713-22, March 29, 1994) and the applicable ACP. Although 40 CFR part 112 does not set required quantities of boom for oil collection and containment, the response plan shall identify and ensure, by contract or other approved means as described in § 112.2, the availability of the quantity of boom identified in the plan for this purpose.
9.6 The plan must indicate the availability of temporary storage capacity to meet section 12.2 of this appendix. If available storage capacity is insufficient to meet this level, then the effective daily recovery capacity must be derated (downgraded) to the limits of the available storage capacity.
9.7 The following is an example of a medium discharge volume planning calculation for equipment identification in a higher volume port area:
The facility’s largest aboveground storage tank volume is 840,000 gallons. Ten percent of this capacity is 84,000 gallons. Because 10 percent of the facility’s largest tank, or 84,000 gallons, is greater than 36,000 gallons, 36,000 gallons is used as the planning volume. The effective daily recovery capacity is 50 percent of the planning volume, or 18,000 gallons per day. The ability of oil recovery devices to meet this capacity must be calculated using the procedures in section 6 of this appendix. Temporary storage capacity available on-scene must equal twice the daily recovery capacity as indicated in section 12.2 of this appendix, or 36,000 gallons per day. This is the information the facility owner or operator must use to identify and ensure the availability of the required response resources, by contract or other approved means as described in § 112.2. The facility owner shall also identify how much boom is available for use.
10.1 A facility owner or operator shall plan for a response to the facility’s worst case discharge. The planning for on-water oil recovery must take into account a loss of some oil to the environment due to physical, chemical, and biological processes, potential increases in volume due to emulsification, and the potential for deposition of oil on the shoreline or on sediments. The response planning procedures for animal fats and vegetable oils are discussed in section 10.7 of this appendix. You may use alternate response planning procedures for animal fats and vegetable oils if those procedures result in environmental protection equivalent to that provided by the procedures in section 10.7 of this appendix.
10.2 The following procedures must be used by a facility owner or operator in determining the required on-water oil recovery capacity:
10.2.1 The following must be determined: the worst case discharge volume of oil in the facility; the appropriate group(s) for the types of oil handled, stored, or transported at the facility (Groups A, B, C); and the facility’s specific operating area. See sections 1.2.1 and 1.2.9 of this appendix for the definitions of animal fats and vegetable oils and groups thereof. Facilities that handle, store, or transport oil from different oil groups must calculate each group separately, unless the oil group constitutes 10 percent or less by volume of the facility’s total oil storage capacity. This information is to be used with Table 6 of this appendix to determine the percentages of the total volume to be used for removal capacity planning. Table 6 of this appendix divides the volume into three categories: oil lost to the environment; oil deposited on the shoreline; and oil available for on-water recovery.
10.2.2 The on-water oil recovery volume shall, as appropriate, be adjusted using the appropriate emulsification factor found in Table 7 of this appendix. Facilities that handle, store, or transport oil from different groups must compare the on-water recovery volume for each oil group (unless the oil group constitutes 10 percent or less by volume of the facility’s total storage capacity) and use the calculation that results in the largest on-water oil recovery volume to plan for the amount of response resources for a worst case discharge.
10.2.3 The adjusted volume is multiplied by the on-water oil recovery resource mobilization factor found in Table 4 of this appendix from the appropriate operating area and response tier to determine the total on-water oil recovery capacity in barrels per day that must be identified or contracted to arrive on-scene within the applicable time for each response tier. Three tiers are specified. For higher volume port areas, the contracted tiers of resources must be located such that they are capable of arriving on-scene within 6 hours for Tier 1, 30 hours for Tier 2, and 54 hours for Tier 3 of the discovery of a discharge. For all other rivers and canals, inland, nearshore areas, and the Great Lakes, these tiers are 12, 36, and 60 hours.
10.2.4 The resulting on-water oil recovery capacity in barrels per day for each tier is used to identify response resources necessary to sustain operations in the applicable operating area. The equipment shall be capable of sustaining operations for the time period specified in Table 6 of this appendix. The facility owner or operator shall identify and ensure, by contract or other approved means as described in § 112.2, the availability of sufficient oil spill recovery devices to provide the effective daily oil recovery capacity required. If the required capacity exceeds the applicable cap specified in Table 5 of this appendix, then a facility owner or operator shall ensure, by contract or other approved means as described in § 112.2, only for the quantity of resources required to meet the cap, but shall identify sources of additional resources as indicated in section 5.4 of this appendix. The owner or operator of a facility whose planning volume exceeded the cap in 1998 must make arrangements to identify and ensure, by contract or other approved means as described in § 112.2, the availability of additional capacity to be under contract by 2003, as appropriate. For a facility that handles multiple groups of oil, the required effective daily recovery capacity for each oil group is calculated before applying the cap. The oil group calculation resulting in the largest on-water recovery volume must be used to plan for the amount of response resources for a worst case discharge, unless the oil group comprises 10 percent or less by volume of the facility’s oil storage capacity.
10.3 The procedures discussed in sections 10.3.1 through 10.3.3 of this appendix must be used to calculate the planning volume for identifying shoreline cleanup capacity (for Groups A and B oils).
10.3.1 The following must be determined: the worst case discharge volume of oil for the facility; the appropriate group(s) for the types of oil handled, stored, or transported at the facility (Groups A or B); and the geographic area(s) in which the facility operates (i.e., operating areas). For a facility handling, storing, or transporting oil from different groups, each group must be calculated separately. Using this information, Table 6 of this appendix must be used to determine the percentages of the total volume to be used for shoreline cleanup resource planning.
10.3.2 The shoreline cleanup planning volume must be adjusted to reflect an emulsification factor using the same procedure as described in section 10.2.2 of this appendix.
10.3.3 The resulting volume shall be used to identify an oil spill removal organization with the appropriate shoreline cleanup capability.
10.4 A response plan must identify response resources with fire fighting capability appropriate for the risk of fire and explosion at the facility from the discharge or threat of discharge of oil. The owner or operator of a facility that handles, stores, or transports Group A or B oils that does not have adequate fire fighting resources located at the facility or that cannot rely on sufficient local fire fighting resources must identify adequate fire fighting resources. The facility owner or operator shall ensure, by contract or other approved means as described in § 112.2, the availability of these resources. The response plan must also identify an individual to work with the fire department for Group A or B oil fires. This individual shall also verify that sufficient well-trained fire fighting resources are available within a reasonable response time to a worst case scenario. The individual may be the qualified individual identified in the response plan or another appropriate individual located at the facility.
10.5 The following is an example of the procedure described in sections 10.2 and 10.3 of this appendix. A facility with a 37.04 million gallon (881,904 barrel) capacity of several types of vegetable oils is located in the Inland Operating Area. The vegetable oil with the highest specific gravity stored at the facility is soybean oil (specific gravity 0.922, Group B vegetable oil). The facility has ten aboveground oil storage tanks with a combined total capacity of 18 million gallons (428,571 barrels) and without secondary containment. The remaining facility tanks are inside secondary containment structures. The largest aboveground oil storage tank (3 million gallons or 71,428 barrels) has its own secondary containment. Two 2.1 million gallon (50,000 barrel) tanks (that are not connected by a manifold) are within a common secondary containment tank area, which is capable of holding 4.2 million gallons (100,000 barrels) plus sufficient freeboard.
10.5.1 The worst case discharge for the facility is calculated by adding the capacity of all aboveground vegetable oil storage tanks without secondary containment (18.0 million gallons) plus the capacity of the largest aboveground storage tank inside secondary containment (3.0 million gallons). The resulting worst case discharge is 21 million gallons or 500,000 barrels.
10.5.2 With a specific worst case discharge identified, the planning volume for on-water recovery can be identified as follows:
| Inland Operating Area | Tier 1 | Tier 2 | Tier 3 |
|---|---|---|---|
| Mobilization factor by which you multiply planning volume | .15 | .25 | .40 |
| Estimated Daily Recovery Capacity (bbls) | 30,000 | 50,000 | 80,000 |
10.5.3 Because the requirements for On-Water Recovery Resources for Tiers 1, 2, and 3 for Inland Operating Area exceed the caps identified in Table 5 of this appendix, the facility owner will contract for a response of 12,500 barrels per day (bpd) for Tier 1, 25,000 bpd for Tier 2, and 50,000 bpd for Tier 3. Resources for the remaining 17,500 bpd for Tier 1, 25,000 bpd for Tier 2, and 30,000 bpd for Tier 3 shall be identified but need not be contracted for in advance.
10.5.4 With the specific worst case discharge identified, the planning volume of onshore recovery can be identified as follows:
10.5.5 The facility owner or operator shall, as appropriate, also identify or contract for quantities of boom identified in the response plan for the protection of fish and wildlife and sensitive environments within the area potentially impacted by a worst case discharge from the facility. For further description of fish and wildlife and sensitive environments, see Appendices I, II, and III to DOC/NOAA’s “Guidance for Facility and Vessel Response Plans: Fish and Wildlife and Sensitive Environments,” (see Appendix E to this part, section 13, for availability) and the applicable ACP. Attachment C-III to Appendix C provides a method for calculating a planning distance to fish and wildlife and sensitive environments and public drinking water intakes that may be adversely affected in the event of a worst case discharge.
10.6 The procedures discussed in sections 10.6.1 through 10.6.3 of this appendix must be used to determine appropriate response resources for facilities with Group C oils.
10.6.1 The owner or operator of a facility that handles, stores, or transports Group C oils shall, as appropriate, identify the response resources available by contract or other approved means, as described in § 112.2. The equipment identified in a response plan shall, as appropriate, include:
(1) Sonar, sampling equipment, or other methods for locating the oil on the bottom or suspended in the water column;
(2) Containment boom, sorbent boom, silt curtains, or other methods for containing the oil that may remain floating on the surface or to reduce spreading on the bottom;
(3) Dredges, pumps, or other equipment necessary to recover oil from the bottom and shoreline;
(4) Equipment necessary to assess the impact of such discharges; and
(5) Other appropriate equipment necessary to respond to a discharge involving the type of oil handled, stored, or transported.
10.6.2 Response resources identified in a response plan for a facility that handles, stores, or transports Group C oils under section 10.6.1 of this appendix shall be capable of being deployed on scene within 24 hours of discovery of a discharge.
10.6.3 A response plan must identify response resources with fire fighting capability. The owner or operator of a facility that handles, stores, or transports Group C oils that does not have adequate fire fighting resources located at the facility or that cannot rely on sufficient local fire fighting resources must identify adequate fire fighting resources. The owner or operator shall ensure, by contract or other approved means as described in § 112.2, the availability of these resources. The response plan shall also identify an individual located at the facility to work with the fire department for Group C oil fires. This individual shall also verify that sufficient well-trained fire fighting resources are available within a reasonable response time to respond to a worst case discharge. The individual may be the qualified individual identified in the response plan or another appropriate individual located at the facility.
10.7 The procedures described in sections 10.7.1 through 10.7.5 of this appendix must be used to determine appropriate response plan development and evaluation criteria for facilities that handle, store, or transport animal fats and vegetable oils. Refer to section 11 of this appendix for information on the limitations on the use of chemical agents for inland and nearshore areas.
10.7.1 An owner or operator of a facility that handles, stores, or transports animal fats and vegetable oils must provide information in the response plan that identifies:
(1) Procedures and strategies for responding to a worst case discharge of animal fats and vegetable oils to the maximum extent practicable; and
(2) Sources of the equipment and supplies necessary to locate, recover, and mitigate such a discharge.
10.7.2 An owner or operator of a facility that handles, stores, or transports animal fats and vegetable oils must ensure that any equipment identified in a response plan is capable of operating in the geographic area(s) (i.e., operating environments) in which the facility operates using the criteria in Table 1 of this appendix. When evaluating the operability of equipment, the facility owner or operator must consider limitations that are identified in the appropriate ACPs, including:
(1) Ice conditions;
(2) Debris;
(3) Temperature ranges; and
(4) Weather-related visibility.
10.7.3. The owner or operator of a facility that handles, stores, or transports animal fats and vegetable oils must identify the response resources that are available by contract or other approved means, as described in § 112.2. The equipment described in the response plan shall, as appropriate, include:
(1) Containment boom, sorbent boom, or other methods for containing oil floating on the surface or to protect shorelines from impact;
(2) Oil recovery devices appropriate for the type of animal fat or vegetable oil carried; and
(3) Other appropriate equipment necessary to respond to a discharge involving the type of oil carried.
10.7.4 Response resources identified in a response plan according to section 10.7.3 of this appendix must be capable of commencing an effective on-scene response within the applicable tier response times in section 5.3 of this appendix.
10.7.5 A response plan must identify response resources with fire fighting capability. The owner or operator of a facility that handles, stores, or transports animal fats and vegetable oils that does not have adequate fire fighting resources located at the facility or that cannot rely on sufficient local fire fighting resources must identify adequate fire fighting resources. The owner or operator shall ensure, by contract or other approved means as described in § 112.2, the availability of these resources. The response plan shall also identify an individual located at the facility to work with the fire department for animal fat and vegetable oil fires. This individual shall also verify that sufficient well-trained fire fighting resources are available within a reasonable response time to respond to a worst case discharge. The individual may be the qualified individual identified in the response plan or another appropriate individual located at the facility.
11.1 For chemical agents to be identified in a response plan, they must be on the NCP Product Schedule that is maintained by EPA. (Some States have a list of approved dispersants for use within State waters. Not all of these State-approved dispersants are listed on the NCP Product Schedule.)
11.2 Identification of chemical agents in the plan does not imply that their use will be authorized. Actual authorization will be governed by the provisions of the NCP and the applicable ACP.
12.1 A facility owner or operator shall identify sufficient response resources available, by contract or other approved means as described in § 112.2, to respond to a medium discharge of animal fats or vegetables oils for that facility. This will require response resources capable of containing and collecting up to 36,000 gallons of oil or 10 percent of the worst case discharge, whichever is less. All equipment identified must be designed to operate in the applicable operating environment specified in Table 1 of this appendix.
12.2 A facility owner or operator shall evaluate the availability of adequate temporary storage capacity to sustain the effective daily recovery capacities from equipment identified in the plan. Because of the inefficiencies of oil spill recovery devices, response plans must identify daily storage capacity equivalent to twice the effective daily recovery capacity required on-scene. This temporary storage capacity may be reduced if a facility owner or operator can demonstrate by waste stream analysis that the efficiencies of the oil recovery devices, ability to decant waste, or the availability of alternative temporary storage or disposal locations will reduce the overall volume of oily material storage.
12.3 A facility owner or operator shall ensure that response planning includes the capability to arrange for disposal of recovered oil products. Specific disposal procedures will be addressed in the applicable ACP.
13.1 All materials listed in this section are part of EPA’s rulemaking docket and are located in the Superfund Docket, 1235 Jefferson Davis Highway, Crystal Gateway 1, Arlington, Virginia 22202, Suite 105 (Docket Numbers SPCC-2P, SPCC-3P, and SPCC-9P). The docket is available for inspection between 9 a.m. and 4 p.m., Monday through Friday, excluding Federal holidays.
Appointments to review the docket can be made by calling 703-603-9232. Docket hours are subject to change. As provided in 40 CFR part 2, a reasonable fee may be charged for copying services.
13.2 The docket will mail copies of materials to requestors who are outside the Washington, DC metropolitan area. Materials may be available from other sources, as noted in this section. As provided in 40 CFR part 2, a reasonable fee may be charged for copying services. The RCRA/Superfund Hotline at 800-424-9346 may also provide additional information on where to obtain documents. To contact the RCRA/Superfund Hotline in the Washington, DC metropolitan area, dial 703-412-9810. The Telecommunications Device for the Deaf (TDD) Hotline number is 800-553-7672, or, in the Washington, DC metropolitan area, 703-412-3323.
(1) National Preparedness for Response Exercise Program (PREP). The PREP draft guidelines are available from United States Coast Guard Headquarters (G-MEP-4), 2100 Second Street, SW., Washington, DC 20593. (See 58 FR 53990-91, October 19, 1993, Notice of Availability of PREP Guidelines).
(2) “Guidance for Facility and Vessel Response Plans: Fish and Wildlife and Sensitive Environments (published in the
(3) ASTM Standards. ASTM F 715, ASTM F 989, ASTM F 631-99, ASTM F 808-83 (1999). The ASTM standards are available from the American Society for Testing and Materials, 100 Barr Harbor Drive, West Conshohocken, PA 19428-2959.
(4) Response Plans for Marine Transportation-Related Facilities, Interim Final Rule. Published by USCG, DOT at 58 FR 7330-76, February 5, 1993.
Table 1 to Appendix E – Response Resource Operating Criteria
| Oil Recovery Devices | ||
|---|---|---|
| Operating environment | Significant wave height 1 | Sea state |
| Rivers and Canals | ≤1 foot | 1 |
| Inland | ≤3 feet | 2 |
| Great Lakes | ≤4 feet | 2-3 |
| Ocean | ≤6 feet | 3-4 |
| Boom | ||||
|---|---|---|---|---|
| Boom property | Use | |||
| Rivers and canals | Inland | Great Lakes | Ocean | |
| Significant Wave Height 1 | ≤1 | ≤3 | ≤4 | ≤6 |
| Sea State | 1 | 2 | 2-3 | 3-4 |
| Boom height – inches (draft plus freeboard) | 6-18 | 18-42 | 18-42 | ≥42 |
| Reserve Buoyancy to Weight Ratio | 2:1 | 2:1 | 2:1 | 3:1 to 4:1 |
| Total Tensile Strength – pounds | 4,500 | 15,000-20,000 | 15,000-20,000 | ≥20,000 |
| Skirt Fabric Tensile Strength – pounds | 200 | 300 | 300 | 500 |
| Skirt Fabric Tear Strength – pounds | 100 | 100 | 100 | 125 |
1 Oil recovery devices and boom
Table 2 to Appendix E – Removal Capacity Planning Table for Petroleum Oils
| Spill location | Rivers and canals | Nearshore/Inland/Great Lakes | ||||
|---|---|---|---|---|---|---|
| Sustainability of on-water oil recovery | 3 days | 4 days | ||||
| Oil group 1 | Percent natural dissipation | Percent recovered floating oil | Percent oil onshore | Percent natural dissipation | Percent recovered floating oil | Percent oil onshore |
| 1 – Non-persistent oils | 80 | 10 | 10 | 80 | 20 | 10 |
| 2 – Light crudes | 40 | 15 | 45 | 50 | 50 | 30 |
| 3 – Medium crudes and fuels | 20 | 15 | 65 | 30 | 50 | 50 |
| 4 – Heavy crudes and fuels | 5 | 20 | 75 | 10 | 50 | 70 |
1 The response resource considerations for non-petroleum oils other than animal fats and vegetable oils are outlined in section 7.7 of this appendix.
Table 3 to Appendix E – Emulsification Factors for Petroleum Oil Groups
1
| Non-Persistent Oil: | |
| Group 1 | 1.0 |
| Persistent Oil: | |
| Group 2 | 1.8 |
| Group 3 | 2.0 |
| Group 4 | 1.4 |
| Group 5 oils are defined in section 1.2.7 of this appendix; the response resource considerations are outlined in section 7.6 of this appendix. |
1 See sections 1.2.2 and 1.2.7 of this appendix for group designations for non-persistent and persistent oils, respectively.
Table 4 to Appendix E – On-Water Oil Recovery Resource Mobilization Factors
| Operating area | Tier 1 | Tier 2 | Tier 3 |
|---|---|---|---|
| Rivers and Canals | 0.30 | 0.40 | 0.60 |
| Inland/Nearshore Great Lakes | 0.15 | 0.25 | 0.40 |
Note: These mobilization factors are for total resources mobilized, not incremental response resources.
Table 5 to Appendix E – Response Capability Caps by Operating Area
| Tier 1 | Tier 2 | Tier 3 | |
|---|---|---|---|
| February 18, 1993: | |||
| All except Rivers & Canals, Great Lakes | 10K bbls/day | 20K bbls/day | 40K bbls/day. |
| Great Lakes | 5K bbls/day | 10K bbls/day | 20K bbls/day. |
| Rivers & Canals | 1.5K bbls/day | 3.0K bbls/day | 6.0K bbls/day. |
| February 18, 1998: | |||
| All except Rivers & Canals, Great Lakes | 12.5K bbls/day | 25K bbls/day | 50K bbls/day. |
| Great Lakes | 6.35K bbls/day | 12.3K bbls/day | 25K bbls/day. |
| Rivers & Canals | 1.875K bbls/day | 3.75K bbls/day | 7.5K bbls/day. |
| February 18, 2003: | |||
| All except Rivers & Canals, Great Lakes | TBD | TBD | TBD. |
| Great Lakes | TBD | TBD | TBD. |
| Rivers & Canals | TBD | TBD | TBD. |
Note: The caps show cumulative overall effective daily recovery capacity, not incremental increases.
TBD = To Be Determined.
Table 6 to Appendix E – Removal Capacity Planning Table for Animal Fats and Vegetable Oils
| Spill location | Rivers and canals | Nearshore/Inland/Great Lakes | ||||
|---|---|---|---|---|---|---|
| Sustainability of on-water oil recovery | 3 days | 4 days | ||||
| Oil group 1 | Percent natural loss | Percent recovered floating oil | Percent recovered oil from onshore | Percent natural loss | Percent recovered floating oil | Percent recovered oil from onshore |
| Group A | 40 | 15 | 45 | 50 | 20 | 30 |
| Group B | 20 | 15 | 65 | 30 | 20 | 50 |
1 Substances with a specific gravity greater than 1.0 generally sink below the surface of the water. Response resource considerations are outlined in section 10.6 of this appendix. The owner or operator of the facility is responsible for determining appropriate response resources for Group C oils including locating oil on the bottom or suspended in the water column; containment boom or other appropriate methods for containing oil that may remain floating on the surface; and dredges, pumps, or other equipment to recover animal fats or vegetable oils from the bottom and shoreline.
Table 7 to Appendix E – Emulsification Factors for Animal Fats and Vegetable Oils
1: | |
| Group A | 1.0 |
| Group B | 2.0 |
1 Substances with a specific gravity greater than 1.0 generally sink below the surface of the water. Response resource considerations are outlined in section 10.6 of this appendix. The owner or operator of the facility is responsible for determining appropriate response resources for Group C oils including locating oil on the bottom or suspended in the water column; containment boom or other appropriate methods for containing oil that may remain floating on the surface; and dredges, pumps, or other equipment to recover animal fats or vegetable oils from the bottom and shoreline.
Appendix F to Part 112 – Facility-Specific Response Plan
(A) Owners or operators of facilities regulated under this part which pose a threat of substantial harm to the environment by discharging oil into or on navigable waters or adjoining shorelines are required to prepare and submit facility-specific response plans to EPA in accordance with the provisions in this appendix. This appendix further describes the required elements in § 112.20(h).
(B) Response plans must be sent to the appropriate EPA Regional office. Figure F-1 of this Appendix lists each EPA Regional office and the address where owners or operators must submit their response plans. Those facilities deemed by the Regional Administrator (RA) to pose a threat of significant and substantial harm to the environment will have their plans reviewed and approved by EPA. In certain cases, information required in the model response plan is similar to information currently maintained in the facility’s Spill Prevention, Control, and Countermeasures (SPCC) Plan as required by 40 CFR 112.3. In these cases, owners or operators may reproduce the information and include a photocopy in the response plan.
(C) A complex may develop a single response plan with a set of core elements for all regulating agencies and separate sections for the non-transportation-related and transportation-related components, as described in § 112.20(h). Owners or operators of large facilities that handle, store, or transport oil at more than one geographically distinct location (e.g., oil storage areas at opposite ends of a single, continuous parcel of property) shall, as appropriate, develop separate sections of the response plan for each storage area.
Several sections of the response plan shall be co-located for easy access by response personnel during an actual emergency or oil discharge. This collection of sections shall be called the Emergency Response Action Plan. The Agency intends that the Action Plan contain only as much information as is necessary to combat the discharge and be arranged so response actions are not delayed. The Action Plan may be arranged in a number of ways. For example, the sections of the Emergency Response Action Plan may be photocopies or condensed versions of the forms included in the associated sections of the response plan. Each Emergency Response Action Plan section may be tabbed for quick reference. The Action Plan shall be maintained in the front of the same binder that contains the complete response plan or it shall be contained in a separate binder. In the latter case, both binders shall be kept together so that the entire plan can be accessed by the qualified individual and appropriate spill response personnel. The Emergency Response Action Plan shall be made up of the following sections:
The facility information form is designed to provide an overview of the site and a description of past activities at the facility. Much of the information required by this section may be obtained from the facility’s existing SPCC Plan.
1.2.1 Facility name and location: Enter facility name and street address. Enter the address of corporate headquarters only if corporate headquarters are physically located at the facility. Include city, county, state, zip code, and phone number.
1.2.2 Latitude and Longitude: Enter the latitude and longitude of the facility. Include degrees, minutes, and seconds of the main entrance of the facility.
1.2.3 Wellhead Protection Area: Indicate if the facility is located in or drains into a wellhead protection area as defined by the Safe Drinking Water Act of 1986 (SDWA).
1.2.4 Owner/operator: Write the name of the company or person operating the facility and the name of the person or company that owns the facility, if the two are different. List the address of the owner, if the two are different.
1.2.5 Qualified Individual: Write the name of the qualified individual for the entire facility. If more than one person is listed, each individual indicated in this section shall have full authority to implement the facility response plan. For each individual, list: name, position, home and work addresses (street addresses, not P.O. boxes), emergency phone number, and specific response training experience.
1.2.6 Date of Oil Storage Start-up: Enter the year which the present facility first started storing oil.
1.2.7 Current Operation: Briefly describe the facility’s operations and include the North American Industrial Classification System (NAICS) code.
1.2.8 Dates and Type of Substantial Expansion: Include information on expansions that have occurred at the facility. Examples of such expansions include, but are not limited to: Throughput expansion, addition of a product line, change of a product line, and installation of additional oil storage capacity. The data provided shall include all facility historical information and detail the expansion of the facility. An example of substantial expansion is any material alteration of the facility which causes the owner or operator of the facility to re-evaluate and increase the response equipment necessary to adequately respond to a worst case discharge from the facility.
(if different from Facility Address)
(A) The information provided in this section shall describe what will be needed in an actual emergency involving the discharge of oil or a combination of hazardous substances and oil discharge. The Emergency Response Information section of the plan must include the following components:
(1) The information provided in the Emergency Notification Phone List in section 1.3.1 identifies and prioritizes the names and phone numbers of the organizations and personnel that need to be notified immediately in the event of an emergency. This section shall include all the appropriate phone numbers for the facility. These numbers must be verified each time the plan is updated. The contact list must be accessible to all facility employees to ensure that, in case of a discharge, any employee on site could immediately notify the appropriate parties.
(2) The Spill Response Notification Form in section 1.3.1 creates a checklist of information that shall be provided to the National Response Center (NRC) and other response personnel. All information on this checklist must be known at the time of notification, or be in the process of being collected. This notification form is based on a similar form used by the NRC. Note: Do not delay spill notification to collect the information on the list.
(3) Section 1.3.2 provides a description of the facility’s list of emergency response equipment and location of the response equipment. When appropriate, the amount of oil that emergency response equipment can handle and any limitations (e.g., launching sites) must be described.
(4) Section 1.3.3 provides information regarding response equipment tests and deployment drills. Response equipment deployment exercises shall be conducted to ensure that response equipment is operational and the personnel who would operate the equipment in a spill response are capable of deploying and operating it. Only a representative sample of each type of response equipment needs to be deployed and operated, as long as the remainder is properly maintained. If appropriate, testing of response equipment may be conducted while it is being deployed. Facilities without facility-owned response equipment must ensure that the oil spill removal organization that is identified in the response plan to provide this response equipment certifies that the deployment exercises have been met. Refer to the National Preparedness for Response Exercise Program (PREP) Guidelines (see appendix E to this part, section 13, for availability), which satisfy Oil Pollution Act (OPA) response exercise requirements.
(5) Section 1.3.4 lists the facility response personnel, including those employed by the facility and those under contract to the facility for response activities, the amount of time needed for personnel to respond, their responsibility in the case of an emergency, and their level of response training. Three different forms are included in this section. The Emergency Response Personnel List shall be composed of all personnel employed by the facility whose duties involve responding to emergencies, including oil discharges, even when they are not physically present at the site. An example of this type of person would be the Building Engineer-in-Charge or Plant Fire Chief. The second form is a list of the Emergency Response Contractors (both primary and secondary) retained by the facility. Any changes in contractor status must be reflected in updates to the response plan. Evidence of contracts with response contractors shall be included in this section so that the availability of resources can be verified. The last form is the Facility Response Team List, which shall be composed of both emergency response personnel (referenced by job title/position) and emergency response contractors, included in one of the two lists described above, that will respond immediately upon discovery of an oil discharge or other emergency (i.e., the first people to respond). These are to be persons normally on the facility premises or primary response contractors. Examples of these personnel would be the Facility Hazardous Materials (HAZMAT) Spill Team 1, Facility Fire Engine Company 1, Production Supervisor, or Transfer Supervisor. Company personnel must be able to respond immediately and adequately if contractor support is not available.
(6) Section 1.3.5 lists factors that must, as appropriate, be considered when preparing an evacuation plan.
(7) Section 1.3.6 references the responsibilities of the qualified individual for the facility in the event of an emergency.
(B) The information provided in the emergency response section will aid in the assessment of the facility’s ability to respond to a worst case discharge and will identify additional assistance that may be needed. In addition, the facility owner or operator may want to produce a wallet-size card containing a checklist of the immediate response and notification steps to be taken in the event of an oil discharge.
| Organization | Phone No. |
|---|---|
| 1. National Response Center (NRC): | 1-800-424-8802 |
| 2. Qualified Individual: | |
| Evening Phone: | |
| 3. Company Response Team: | |
| Evening Phone: | |
| 4. Federal On-Scene Coordinator (OSC) and/or Regional Response Center (RRC): | |
| Evening Phone(s): | |
| Pager Number(s): | |
| 5. Local Response Team (Fire Dept./Cooperatives): | |
| 6. Fire Marshall: | |
| Evening Phone: | |
| 7. State Emergency Response Commission (SERC): | |
| Evening Phone: | |
| 8. State Police: | |
| 9. Local Emergency Planning Committee (LEPC): | |
| 10. Local Water Supply System: | |
| Evening Phone: | |
| 11. Weather Report: | |
| 12. Local Television/Radio Station for Evacuation Notification: | |
| 13. Hospitals: |
| CHRIS Code | Discharged quantity | Unit of measure | Material Discharged in water | Quantity | Unit of measure |
|---|---|---|---|---|---|
Date of Last Update:___
3. Chemicals Stored (Dispersants listed on EPA’s NCP Product Schedule)
| Type | Amount | Date purchased | Treatment capacity | Storage location |
|---|---|---|---|---|
Were appropriate procedures used to receive approval for use of dispersants in accordance with the NCP (40 CFR 300.910) and the Area Contingency Plan (ACP), where applicable?___ (Y/N).
Name and State of On-Scene Coordinator (OSC) authorizing use: ___ .
Date Authorized: ___ .
4. Dispersant Dispensing Equipment – Operational Status: ___ .
| Type and year | Capacity | Storage location | Response time (minutes) |
|---|---|---|---|
| Type and year | Quantity | Storage location |
|---|---|---|
7. Communication Equipment (include operating frequency and channel and/or cellular phone numbers) – Operational Status: ___
| Type and year | Quantity | Storage location/number |
|---|---|---|
8. Fire Fighting and Personnel Protective Equipment – Operational Status: ___
| Type and year | Quantity | Storage location |
|---|---|---|
9. Other (e.g., Heavy Equipment, Boats and Motors) – Operational Status: ___
| Type and year | Quantity | Storage location |
|---|---|---|
Date of Last Update:____
Date of Last Update:____
Emergency Response Personnel
Company Personnel
| Name | Phone 1 | Response time | Responsibility during response action | Response training type/date |
|---|---|---|---|---|
| 1. | ||||
| 2. | ||||
| 3. | ||||
| 4. | ||||
| 5. | ||||
| 6. | ||||
| 7. | ||||
| 8. | ||||
| 9. | ||||
| 10. | ||||
| 11. | ||||
| 12. |
1 Phone number to be used when person is not on-site.
Emergency Response Contractors
Date of Last Update: ____
| Contractor | Phone | Response time | Contract responsibility 1 |
|---|---|---|---|
| 1. | |||
| 2. | |||
| 3. | |||
| 4. | |||
1 Include evidence of contracts/agreements with response contractors to ensure the availability of personnel and response equipment.
Facility Response Team
Date of Last Update:____
| Team member | Response time (minutes) | Phone or pager number (day/evening) |
|---|---|---|
| Qualified Individual: | ||
| / | ||
| / | ||
| / | ||
| / | ||
| / | ||
| / | ||
| / | ||
| / | ||
| / | ||
| / | ||
| / | ||
| / | ||
| / | ||
| / | ||
| / | ||
| / | ||
| / | ||
| / |
1.3.5.1 Based on the analysis of the facility, as discussed elsewhere in the plan, a facility-wide evacuation plan shall be developed. In addition, plans to evacuate parts of the facility that are at a high risk of exposure in the event of a discharge or other release must be developed. Evacuation routes must be shown on a diagram of the facility (see section 1.9 of this appendix). When developing evacuation plans, consideration must be given to the following factors, as appropriate:
(1) Location of stored materials;
(2) Hazard imposed by discharged material;
(3) Discharge flow direction;
(4) Prevailing wind direction and speed;
(5) Water currents, tides, or wave conditions (if applicable);
(6) Arrival route of emergency response personnel and response equipment;
(7) Evacuation routes;
(8) Alternative routes of evacuation;
(9) Transportation of injured personnel to nearest emergency medical facility;
(10) Location of alarm/notification systems;
(11) The need for a centralized check-in area for evacuation validation (roll call);
(12) Selection of a mitigation command center; and
(13) Location of shelter at the facility as an alternative to evacuation.
1.3.5.2 One resource that may be helpful to owners or operators in preparing this section of the response plan is The Handbook of Chemical Hazard Analysis Procedures by the Federal Emergency Management Agency (FEMA), Department of Transportation (DOT), and EPA. The Handbook of Chemical Hazard Analysis Procedures is available from: FEMA , Publication Office, 500 C. Street, S.W., Washington, DC 20472, (202) 646-3484.
1.3.5.3 As specified in § 112.20(h)(1)(vi), the facility owner or operator must reference existing community evacuation plans, as appropriate.
The duties of the designated qualified individual are specified in § 112.20(h)(3)(ix). The qualified individual’s duties must be described and be consistent with the minimum requirements in § 112.20(h)(3)(ix). In addition, the qualified individual must be identified with the Facility Information in section 1.2 of the response plan.
This section requires the facility owner or operator to examine the facility’s operations closely and to predict where discharges could occur. Hazard evaluation is a widely used industry practice that allows facility owners or operators to develop a complete understanding of potential hazards and the response actions necessary to address these hazards. The Handbook of Chemical Hazard Analysis Procedures, prepared by the EPA, DOT, and the FEMA and the Hazardous Materials Emergency Planning Guide (NRT-1), prepared by the National Response Team are good references for conducting a hazard analysis. Hazard identification and evaluation will assist facility owners or operators in planning for potential discharges, thereby reducing the severity of discharge impacts that may occur in the future. The evaluation also may help the operator identify and correct potential sources of discharges. In addition, special hazards to workers and emergency response personnel’s health and safety shall be evaluated, as well as the facility’s oil spill history.
The Tank and Surface Impoundment (SI) forms, or their equivalent, that are part of this section must be completed according to the directions below. (“Surface Impoundment” means a facility or part of a facility which is a natural topographic depression, man-made excavation, or diked area formed primarily of earthen materials (although it may be lined with man-made materials), which is designed to hold an accumulation of liquid wastes or wastes containing free liquids, and which is not an injection well or a seepage facility.) Similar worksheets, or their equivalent, must be developed for any other type of storage containers.
(1) List each tank at the facility with a separate and distinct identifier. Begin aboveground tank identifiers with an “A” and belowground tank identifiers with a “B”, or submit multiple sheets with the aboveground tanks and belowground tanks on separate sheets.
(2) Use gallons for the maximum capacity of a tank; and use square feet for the area.
(3) Using the appropriate identifiers and the following instructions, fill in the appropriate forms:
(a) Tank or SI number – Using the aforementioned identifiers (A or B) or multiple reporting sheets, identify each tank or SI at the facility that stores oil or hazardous materials.
(b) Substance Stored – For each tank or SI identified, record the material that is stored therein. If the tank or SI is used to store more than one material, list all of the stored materials.
(c) Quantity Stored – For each material stored in each tank or SI, report the average volume of material stored on any given day.
(d) Tank Type or Surface Area/Year – For each tank, report the type of tank (e.g., floating top), and the year the tank was originally installed. If the tank has been refabricated, the year that the latest refabrication was completed must be recorded in parentheses next to the year installed. For each SI, record the surface area of the impoundment and the year it went into service.
(e) Maximum Capacity – Record the operational maximum capacity for each tank and SI. If the maximum capacity varies with the season, record the upper and lower limits.
(f) Failure/Cause – Record the cause and date of any tank or SI failure which has resulted in a loss of tank or SI contents.
(4) Using the numbers from the tank and SI forms, label a schematic drawing of the facility. This drawing shall be identical to any schematic drawings included in the SPCC Plan.
(5) Using knowledge of the facility and its operations, describe the following in writing:
(a) The loading and unloading of transportation vehicles that risk the discharge of oil or release of hazardous substances during transport processes. These operations may include loading and unloading of trucks, railroad cars, or vessels. Estimate the volume of material involved in transfer operations, if the exact volume cannot be determined.
(b) Day-to-day operations that may present a risk of discharging oil or releasing a hazardous substance. These activities include scheduled venting, piping repair or replacement, valve maintenance, transfer of tank contents from one tank to another, etc. (not including transportation-related activities). Estimate the volume of material involved in these operations, if the exact volume cannot be determined.
(c) The secondary containment volume associated with each tank and/or transfer point at the facility. The numbering scheme developed on the tables, or an equivalent system, must be used to identify each containment area. Capacities must be listed for each individual unit (tanks, slumps, drainage traps, and ponds), as well as the facility total.
(d) Normal daily throughput for the facility and any effect on potential discharge volumes that a negative or positive change in that throughput may cause.
Hazard Identification Tanks
1
Date of Last Update: ____
| Tank No. | Substance Stored (Oil and Hazardous Substance) | Quantity Stored (gallons) | Tank Type/Year | Maximum Capacity (gallons) | Failure/Cause |
|---|---|---|---|---|---|
1 Tank = any container that stores oil.
Attach as many sheets as necessary.
Hazard Identification Surface Impoundments (SIs)
Date of Last Update: ____
| SI No. | Substance Stored | Quantity Stored (gallons) | Surface Area/Year | Maximum Capacity (gallons) | Failure/Cause |
|---|---|---|---|---|---|
Attach as many sheets as necessary.
The vulnerability analysis shall address the potential effects (i.e., to human health, property, or the environment) of an oil discharge. Attachment C-III to Appendix C to this part provides a method that owners or operators shall use to determine appropriate distances from the facility to fish and wildlife and sensitive environments. Owners or operators can use a comparable formula that is considered acceptable by the RA. If a comparable formula is used, documentation of the reliability and analytical soundness of the formula must be attached to the response plan cover sheet. This analysis must be prepared for each facility and, as appropriate, must discuss the vulnerability of:
(1) Water intakes (drinking, cooling, or other);
(2) Schools;
(3) Medical facilities;
(4) Residential areas;
(5) Businesses;
(6) Wetlands or other sensitive environments;
(7) Fish and wildlife;
(8) Lakes and streams;
(9) Endangered flora and fauna;
(10) Recreational areas;
(11) Transportation routes (air, land, and water);
(12) Utilities; and
(13) Other areas of economic importance (e.g., beaches, marinas) including terrestrially sensitive environments, aquatic environments, and unique habitats.
Each owner or operator shall analyze the probability of a discharge occurring at the facility. This analysis shall incorporate factors such as oil discharge history, horizontal range of a potential discharge, and vulnerability to natural disaster, and shall, as appropriate, incorporate other factors such as tank age. This analysis will provide information for developing discharge scenarios for a worst case discharge and small and medium discharges and aid in the development of techniques to reduce the size and frequency of discharges. The owner or operator may need to research the age of the tanks the oil discharge history at the facility.
Briefly describe the facility’s reportable oil spill
(1) Date of discharge(s);
(2) List of discharge causes;
(3) Material(s) discharged;
(4) Amount discharged in gallons;
(5) Amount of discharge that reached navigable waters, if applicable;
(6) Effectiveness and capacity of secondary containment;
(7) Clean-up actions taken;
(8) Steps taken to reduce possibility of recurrence;
(9) Total oil storage capacity of the tank(s) or impoundment(s) from which the material discharged;
(10) Enforcement actions;
(11) Effectiveness of monitoring equipment; and
(12) Description(s) of how each oil discharge was detected.
In this section, the owner or operator is required to provide a description of the facility’s worst case discharge, as well as a small and medium discharge, as appropriate. A multi-level planning approach has been chosen because the response actions to a discharge (i.e., necessary response equipment, products, and personnel) are dependent on the magnitude of the discharge. Planning for lesser discharges is necessary because the nature of the response may be qualitatively different depending on the quantity of the discharge. The facility owner or operator shall discuss the potential direction of the discharge pathway.
1.5.1.1 To address multi-level planning requirements, the owner or operator must consider types of facility-specific discharge scenarios that may contribute to a small or medium discharge. The scenarios shall account for all the operations that take place at the facility, including but not limited to:
(1) Loading and unloading of surface transportation;
(2) Facility maintenance;
(3) Facility piping;
(4) Pumping stations and sumps;
(5) Oil storage tanks;
(6) Vehicle refueling; and
(7) Age and condition of facility and components.
1.5.1.2 The scenarios shall also consider factors that affect the response efforts required by the facility. These include but are not limited to:
(1) Size of the discharge;
(2) Proximity to downgradient wells, waterways, and drinking water intakes;
(3) Proximity to fish and wildlife and sensitive environments;
(4) Likelihood that the discharge will travel offsite (i.e., topography, drainage);
(5) Location of the material discharged (i.e., on a concrete pad or directly on the soil);
(6) Material discharged;
(7) Weather or aquatic conditions (i.e., river flow);
(8) Available remediation equipment;
(9) Probability of a chain reaction of failures; and
(10) Direction of discharge pathway.
1.5.2.1 In this section, the owner or operator must identify the worst case discharge volume at the facility. Worksheets for production and non-production facility owners or operators to use when calculating worst case discharge are presented in appendix D to this part. When planning for the worst case discharge response, all of the aforementioned factors listed in the small and medium discharge section of the response plan shall be addressed.
1.5.2.2 For onshore storage facilities and production facilities, permanently manifolded oil storage tanks are defined as tanks that are designed, installed, and/or operated in such a manner that the multiple tanks function as one storage unit (i.e., multiple tank volumes are equalized). In this section of the response plan, owners or operators must provide evidence that oil storage tanks with common piping or piping systems are not operated as one unit. If such evidence is provided and is acceptable to the RA, the worst case discharge volume shall be based on the combined oil storage capacity of all manifold tanks or the oil storage capacity of the largest single oil storage tank within the secondary containment area, whichever is greater. For permanently manifolded oil storage tanks that function as one storage unit, the worst case discharge shall be based on the combined oil storage capacity of all manifolded tanks or the oil storage capacity of the largest single tank within a secondary containment area, whichever is greater. For purposes of the worst case discharge calculation, permanently manifolded oil storage tanks that are separated by internal divisions for each tank are considered to be single tanks and individual manifolded tank volumes are not combined.
In this section, the facility owner or operator shall provide a detailed description of the procedures and equipment used to detect discharges. A section on discharge detection by personnel and a discussion of automated discharge detection, if applicable, shall be included for both regular operations and after hours operations. In addition, the facility owner or operator shall discuss how the reliability of any automated system will be checked and how frequently the system will be inspected.
In this section, facility owners or operators shall describe the procedures and personnel that will detect any discharge of oil or release of a hazardous substance. A thorough discussion of facility inspections must be included. In addition, a description of initial response actions shall be addressed. This section shall reference section 1.3.1 of the response plan for emergency response information.
In this section, facility owners or operators must describe any automated discharge detection equipment that the facility has in place. This section shall include a discussion of overfill alarms, secondary containment sensors, etc. A discussion of the plans to verify an automated alarm and the actions to be taken once verified must also be included.
In this section, facility owners or operators must explain in detail how to implement the facility’s emergency response plan by describing response actions to be carried out under the plan to ensure the safety of the facility and to mitigate or prevent discharges described in section 1.5 of the response plan. This section shall include the identification of response resources for small, medium, and worst case discharges; disposal plans; and containment and drainage planning. A list of those personnel who would be involved in the cleanup shall be identified. Procedures that the facility will use, where appropriate or necessary, to update their plan after an oil discharge event and the time frame to update the plan must be described.
1.7.1.1 Once the discharge scenarios have been identified in section 1.5 of the response plan, the facility owner or operator shall identify and describe implementation of the response actions. The facility owner or operator shall demonstrate accessibility to the proper response personnel and equipment to effectively respond to all of the identified discharge scenarios. The determination and demonstration of adequate response capability are presented in appendix E to this part. In addition, steps to expedite the cleanup of oil discharges must be discussed. At a minimum, the following items must be addressed:
(1) Emergency plans for spill response;
(2) Additional response training;
(3) Additional contracted help;
(4) Access to additional response equipment/experts; and
(5) Ability to implement the plan including response training and practice drills.
1.7.1.2A recommended form detailing immediate actions follows.
Oil Spill Response – Immediate Actions
| 1. Stop the product flow | Act quickly to secure pumps, close valves, etc. |
| 2. Warn personnel | Enforce safety and security measures. |
| 3. Shut off ignition sources | Motors, electrical circuits, open flames, etc. |
| 4. Initiate containment | Around the tank and/or in the water with oil boom. |
| 5. Notify NRC | 1-800-424-8802 |
| 6. Notify OSC | |
| 7. Notify, as appropriate |
Source: FOSS, Oil Spill Response – Emergency Procedures, Revised December 3, 1992.
1.7.2.1 Facility owners or operators must describe how and where the facility intends to recover, reuse, decontaminate, or dispose of materials after a discharge has taken place. The appropriate permits required to transport or dispose of recovered materials according to local, State, and Federal requirements must be addressed. Materials that must be accounted for in the disposal plan, as appropriate, include:
(1) Recovered product;
(2) Contaminated soil;
(3) Contaminated equipment and materials, including drums, tank parts, valves, and shovels;
(4) Personnel protective equipment;
(5) Decontamination solutions;
(6) Adsorbents; and
(7) Spent chemicals.
1.7.2.2 These plans must be prepared in accordance with Federal (e.g., the Resource Conservation and Recovery Act [RCRA]), State, and local regulations, where applicable. A copy of the disposal plans from the facility’s SPCC Plan may be inserted with this section, including any diagrams in those plans.
| Material | Disposal facility | Location | RCRA permit/manifest |
|---|---|---|---|
| 1. | |||
| 2. | |||
| 3. | |||
| 4. |
A proper plan to contain and control a discharge through drainage may limit the threat of harm to human health and the environment. This section shall describe how to contain and control a discharge through drainage, including:
(1) The available volume of containment (use the information presented in section 1.4.1 of the response plan);
(2) The route of drainage from oil storage and transfer areas;
(3) The construction materials used in drainage troughs;
(4) The type and number of valves and separators used in the drainage system;
(5) Sump pump capacities;
(6) The containment capacity of weirs and booms that might be used and their location (see section 1.3.2 of this appendix); and
(7) Other cleanup materials.
In addition, a facility owner or operator must meet the inspection and monitoring requirements for drainage contained in 40 CFR part 112, subparts A through C. A copy of the containment and drainage plans that are required in 40 CFR part 112, subparts A through C may be inserted in this section, including any diagrams in those plans.
The general permit for stormwater drainage may contain additional requirements.
The owner or operator must develop programs for facility response training and for drills/exercises according to the requirements of 40 CFR 112.21. Logs must be kept for facility drills/exercises, personnel response training, and spill prevention meetings. Much of the recordkeeping information required by this section is also contained in the SPCC Plan required by 40 CFR 112.3. These logs may be included in the facility response plan or kept as an annex to the facility response plan.
Under 40 CFR 112.7(e), you must include the written procedures and records of inspections for each facility in the SPCC Plan. You must include the inspection records for each container, secondary containment, and item of response equipment at the facility. You must cross-reference the records of inspections of each container and secondary containment required by 40 CFR 112.7(e) in the facility response plan. The inspection record of response equipment is a new requirement in this plan. Facility self-inspection requires two-steps: (1) a checklist of things to inspect; and (2) a method of recording the actual inspection and its findings. You must note the date of each inspection. You must keep facility response plan records for five years. You must keep SPCC records for three years.
The tank inspection checklist presented below has been included as guidance during inspections and monitoring. Similar requirements exist in 40 CFR part 112, subparts A through C. Duplicate information from the SPCC Plan may be photocopied and inserted in this section. The inspection checklist consists of the following items:
Tank/Surface Impoundment Inspection Log
| Inspector | Tank or SI# | Date | Comments |
|---|---|---|---|
Using the Emergency Response Equipment List provided in section 1.3.2 of the response plan, describe each type of response equipment, checking for the following:
1. Inventory (item and quantity);
2. Storage location;
3. Accessibility (time to access and respond);
4. Operational status/condition;
5. Actual use/testing (last test date and frequency of testing); and
6. Shelf life (present age, expected replacement date).
Response Equipment Inspection Log
[Use section 1.3.2 of the response plan as a checklist]
| Inspector | Date | Comments |
|---|---|---|
Inspect the secondary containment (as described in sections 1.4.1 and 1.7.2 of the response plan), checking the following:
(A) CWA section 311(j)(5), as amended by OPA, requires the response plan to contain a description of facility drills/exercises. According to 40 CFR 112.21(c), the facility owner or operator shall develop a program of facility response drills/exercises, including evaluation procedures. Following the PREP guidelines (see appendix E to this part, section 13, for availability) would satisfy a facility’s requirements for drills/exercises under this part. Alternately, under § 112.21(c), a facility owner or operator may develop a program that is not based on the PREP guidelines. Such a program is subject to approval by the Regional Administrator based on the description of the program provided in the response plan.
(B) The PREP Guidelines specify that the facility conduct internal and external drills/exercises. The internal exercises include: qualified individual notification drills, spill management team tabletop exercises, equipment deployment exercises, and unannounced exercises. External exercises include Area Exercises. Credit for an Area or Facility-specific Exercise will be given to the facility for an actual response to a discharge in the area if the plan was utilized for response to the discharge and the objectives of the Exercise were met and were properly evaluated, documented, and self-certified.
(C) Section 112.20(h)(8)(ii) requires the facility owner or operator to provide a description of the drill/exercise program to be carried out under the response plan. Qualified Individual Notification Drill and Spill Management Team Tabletop Drill logs shall be provided in sections 1.8.2.1 and 1.8.2.2, respectively. These logs may be included in the facility response plan or kept as an annex to the facility response plan. See section 1.3.3 of this appendix for Equipment Deployment Drill Logs.
Section 112.21(a) requires facility owners or operators to develop programs for facility response training. Facility owners or operators are required by § 112.20(h)(8)(iii) to provide a description of the response training program to be carried out under the response plan. A facility’s training program can be based on the USCG’s Training Elements for Oil Spill Response, to the extent applicable to facility operations, or another response training program acceptable to the RA. The training elements are available from the USCG Office of Response (G-MOR) at (202) 267-0518 or fax (202) 267-4085. Personnel response training logs and discharge prevention meeting logs shall be included in sections 1.8.3.1 and 1.8.3.2 of the response plan respectively. These logs may be included in the facility response plan or kept as an annex to the facility response plan.
Personnel Response Training Log
| Name | Response training/date and number of hours | Prevention training/date and number of hours |
|---|---|---|
| Subject/issue identified | Required action | Implementation date |
|---|---|---|
The facility-specific response plan shall include the following diagrams. Additional diagrams that would aid in the development of response plan sections may also be included.
According to 40 CFR 112.7(g) facilities are required to maintain a certain level of security, as appropriate. In this section, a description of the facility security shall be provided and include, as appropriate:
A three-page form has been developed to be completed and submitted to the RA by owners or operators who are required to prepare and submit a facility-specific response plan. The cover sheet (Attachment F-1) must accompany the response plan to provide the Agency with basic information concerning the facility. This section will describe the Response Plan Cover Sheet and provide instructions for its completion.
Owner/Operator of Facility: Enter the name of the owner of the facility (if the owner is the operator). Enter the operator of the facility if otherwise. If the owner/operator of the facility is a corporation, enter the name of the facility’s principal corporate executive. Enter as much of the name as will fit in each section.
(1) Facility Name: Enter the proper name of the facility.
(2) Facility Address: Enter the street address, city, State, and zip code.
(3) Facility Phone Number: Enter the phone number of the facility.
(4) Latitude and Longitude: Enter the facility latitude and longitude in degrees, minutes, and seconds.
(5) Dun and Bradstreet Number: Enter the facility’s Dun and Bradstreet number if available (this information may be obtained from public library resources).
(6) North American Industrial Classification System (NAICS) Code: Enter the facility’s NAICS code as determined by the Office of Management and Budget (this information may be obtained from public library resources.)
(7) Largest Oil Storage Tank Capacity: Enter the capacity in GALLONS of the largest aboveground oil storage tank at the facility.
(8) Maximum Oil Storage Capacity: Enter the total maximum capacity in GALLONS of all aboveground oil storage tanks at the facility.
(9) Number of Oil Storage Tanks: Enter the number of all aboveground oil storage tanks at the facility.
(10) Worst Case Discharge Amount: Using information from the worksheets in appendix D, enter the amount of the worst case discharge in GALLONS.
(11) Facility Distance to Navigable Waters: Mark the appropriate line for the nearest distance between an opportunity for discharge (i.e., oil storage tank, piping, or flowline) and a navigable water.
Using the flowchart provided in Attachment C-I to appendix C to this part, mark the appropriate answer to each question. Explanations of referenced terms can be found in Appendix C to this part. If a comparable formula to the ones described in Attachment C-III to appendix C to this part is used to calculate the planning distance, documentation of the reliability and analytical soundness of the formula must be attached to the response plan cover sheet.
Complete this block after all other questions have been answered.
CONCAWE. 1982. Methodologies for Hazard Analysis and Risk Assessment in the Petroleum Refining and Storage Industry. Prepared by CONCAWE’s Risk Assessment Ad-hoc Group.
U.S. Department of Housing and Urban Development. 1987. Siting of HUD-Assisted Projects Near Hazardous Facilities: Acceptable Separation Distances from Explosive and Flammable Hazards. Prepared by the Office of Environment and Energy, Environmental Planning Division, Department of Housing and Urban Development. Washington, DC.
U.S. DOT, FEMA and U.S. EPA. Handbook of Chemical Hazard Analysis Procedures.
U.S. DOT, FEMA and U.S. EPA. Technical Guidance for Hazards Analysis: Emergency Planning for Extremely Hazardous Substances.
The National Response Team. 1987. Hazardous Materials Emergency Planning Guide. Washington, DC.
The National Response Team. 1990. Oil Spill Contingency Planning, National Status: A Report to the President. Washington, DC. U.S. Government Printing Office.
Offshore Inspection and Enforcement Division. 1988. Minerals Management Service, Offshore Inspection Program: National Potential Incident of Noncompliance (PINC) List. Reston, VA.
This cover sheet will provide EPA with basic information concerning the facility. It must accompany a submitted facility response plan. Explanations and detailed instructions can be found in appendix F. Please type or write legibly in blue or black ink. Public reporting burden for the collection of this information is estimated to vary from 1 hour to 270 hours per response in the first year, with an average of 5 hours per response. This estimate includes time for reviewing instructions, searching existing data sources, gathering the data needed, and completing and reviewing the collection of information. Send comments regarding the burden estimate of this information, including suggestions for reducing this burden to: Chief, Information Policy Branch, Mail Code: PM-2822, U.S. Environmental Protection Agency, Ariel Rios Building, 1200 Pennsylvania Avenue, NW., Washington, DC 20460; and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington D.C. 20503.
Does the facility transfer oil over-water
Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and, within any storage area, does the facility lack secondary containment
Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and is the facility located at a distance
Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and has the facility experienced a reportable oil spill
I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document, and that based on my inquiry of those individuals responsible for obtaining information, I believe that the submitted information is true, accurate, and complete.
Appendix G to Part 112 – Tier I Qualified Facility SPCC Plan
PART 113 – LIABILITY LIMITS FOR SMALL ONSHORE STORAGE FACILITIES
Subpart A – Oil Storage Facilities
§ 113.1 Purpose.
This subpart establishes size classifications and associated liability limits for small onshore oil storage facilities with fixed capacity of 1,000 barrels or less.
§ 113.2 Applicability.
This subpart applies to all onshore oil storage facilities with fixed capacity of 1,000 barrels or less. When a discharge to the waters of the United States occurs from such facilities and when removal of said discharge is performed by the United States Government pursuant to the provisions of subsection 311(c)(1) of the Act, the liability of the owner or operator and the facility will be limited to the amounts specified in § 113.4.
§ 113.3 Definitions.
As used in this subpart, the following terms shall have the meanings indicated below:
(a) Aboveground storage facility means a tank or other container, the bottom of which is on a plane not more than 6 inches below the surrounding surface.
(b) Act means the Federal Water Pollution Control Act, as amended, 33 U.S.C. 1151, et seq.
(c) Barrel means 42 United States gallons at 60 degrees Fahrenheit.
(d) Belowground storage facility means a tank or other container located other than as defined as “Aboveground”.
(e) Discharge includes, but is not limited to any spilling, leaking, pumping, pouring, emitting, emptying or dumping.
(f) Onshore Oil Storage Facility means any facility (excluding motor vehicles and rolling stock) of any kind located in, on, or under, any land within the United States, other than submerged land.
(g) On-Scene Coordinator is the single Federal representative designated pursuant to the National Oil and Hazardous Substances Pollution Contingency Plan and identified in approved Regional Oil and Hazardous Substances Pollution Contingency Plans.
(h) Oil means oil of any kind or in any form, including but not limited to, petroleum, fuel oil, sludge, oil refuse, and oil mixed with wastes other than dredged spoil.
(i) Remove or removal means the removal of the oil from the water and shorelines or the taking of such other actions as the Federal On-Scene Coordinator may determine to be necessary to minimize or mitigate damage to the public health or welfare, including but not limited to, fish, shellfish, wildlife, and public and private property, shorelines, and beaches.
§ 113.4 Size classes and associated liability limits for fixed onshore oil storage facilities, 1,000 barrels or less capacity.
Unless the United States can show that oil was discharged as a result of willful negligence or willful misconduct within the privity and knowledge of the owner or operator, the following limits of liability are established for fixed onshore facilities in the classes specified:
(a) Aboveground storage.
| Size class | Capacity (barrels) | Limit (dollars) |
|---|---|---|
| I | Up to 10 | 4,000 |
| II | 11 to 170 | 60,000 |
| III | 171 to 500 | 150,000 |
| IV | 501 to 1,000 | 200,000 |
(b) Belowground storage.
| Size class | Capacity (barrels) | Limit (dollars) |
|---|---|---|
| I | Up to 10 | 5,200 |
| II | 11 to 170 | 78,000 |
| III | 171 to 500 | 195,000 |
| IV | 501 to 1,000 | 260,000 |
§ 113.5 Exclusions.
This subpart does not apply to:
(a) Those facilities whose average daily oil throughout is more than their fixed oil storage capacity.
(b) Vehicles and rolling stock.
§ 113.6 Effect on other laws.
Nothing herein shall be construed to limit the liability of any facility under State or local law or under any Federal law other than section 311 of the Act, nor shall the liability of any facility for any charges or damages under State or local law reduce its liability to the Federal Government under section 311 of the Act, as limited by this subpart.
PART 116 – DESIGNATION OF HAZARDOUS SUBSTANCES
§ 116.1 Applicability.
This regulation designates hazardous substances under section 311(b)(2)(A) of the Federal Water Pollution Control Act (the Act). The regulation applies to discharges of substances designated in Table 116.4.
§ 116.2 Abbreviations.
§ 116.3 Definitions.
As used in this part, all terms shall have the meaning defined in the Act and as given below:
The Act means the Federal Water Pollution Control Act, as amended by the Federal Water Pollution Control Act Amendments of 1972 (Pub. L. 92-500), and as further amended by the Clean Water Act of 1977 (Pub. L. 95-217), 33 U.S.C. 1251 et seq.; and as further amended by the Clean Water Act Amendments of 1978 (Pub. L. 95-676);
Animals means appropriately sensitive animals which carry out respiration by means of a lung structure permitting gaseous exchange between air and the circulatory system;
Aquatic animals means appropriately sensitive wholly aquatic animals which carry out respiration by means of a gill structure permitting gaseous exchange between the water and the circulatory system;
Aquatic flora means plant life associated with the aquatic eco-system including, but not limited to, algae and higher plants;
Contiguous zone means the entire zone established or to be established by the United States under article 24 of the Convention of the Territorial Sea and the Contiguous Zone;
Discharge includes, but is not limited to, any spilling, leaking, pumping, pouring, emitting, emptying or dumping, but excludes (A) discharges in compliance with a permit under section 402 of this Act, (B) discharges resulting from circumstances identified and reviewed and made a part of the public record with respect to a permit issued or modified under section 402 of this Act, and subject to a condition in such permit, and (C) continuous or anticipated intermittent discharges from a point source, identified in a permit or permit application under section 402 of this Act, which are caused by events occurring within the scope of relevant operating or treatment systems;
LC50 means that concentration of material which is lethal to one-half of the test population of aquatic animals upon continuous exposure for 96 hours or less.
Mixture means any combination of two or more elements and/or compounds in solid, liquid, or gaseous form except where such substances have undergone a chemical reaction so as to become inseparable by physical means.
Navigable waters means “waters of the United States,” including the territorial seas, as defined in § 120.2 of this chapter.
Offshore facility means any facility of any kind located in, on, or under, any of the navigable waters of the United States, and any facility of any kind which is subject to the jurisdiction of the United States and is located in, on, or under any other waters, other than a vessel or a public vessel;
Onshore facility means any facility (including, but not limited to, motor vehicles and rolling stock) of any kind located in, on, or under, any land within the United States other than submerged land;
Otherwise subject to the jurisdiction of the United States means subject to the jurisdiction of the United States by virtue of United States citizenship, United States vessel documentation or numbering, or as provided for by international agreement to which the United States is a party.
A discharge in connection with activities under the Outer Continental Shelf Lands Act or the Deepwater Port Act of 1974, or which may affect natural resources belonging to, appertaining to, or under the exclusive management authority of the United States (including resources under the Fishery Conservation and Management Act of 1976), means: (1) A discharge into any waters beyond the contiguous zone from any vessel or onshore or offshore facility, which vessel or facility is subject to or is engaged in activities under the Outer Continental Shelf Lands Act or the Deepwater Port Act of 1974, and (2) any discharge into any waters beyond the contiguous zone which contain, cover, or support any natural resource belonging to, appertaining to, or under the exclusive management authority of the United States (including resources under the Fishery Conservation and Management Act of 1976).
Public vessel means a vessel owned or bareboat-chartered and operated by the United States, or a State or political subdivision thereof, or by a foreign nation, except when such vessel is engaged in commerce.
Territorial seas means the belt of the seas measured from the line of ordinary low water along that portion of the coast which is in direct contact with the open sea and the line marking the seaward limit of inland waters, and extending seaward a distance of 3 miles.
Vessel means every description of watercraft or other artificial contrivance used, or capable of being used, as a means of transportation on water other than a public vessel;
§ 116.4 Designation of hazardous substances.
The elements and compounds appearing in Tables 116.4 A and B are designated as hazardous substances in accordance with section 311(b)(2)(A) of the Act. This designation includes any isomers and hydrates, as well as any solutions and mixtures containing these substances. Synonyms and Chemical Abstract System (CAS) numbers have been added for convenience of the user only. In case of any disparity the common names shall be considered the designated substance.
Table 116.4A – List of Hazardous Substances
| Common name | CAS No. | Synonyms | Isomers | CAS No. |
|---|---|---|---|---|
| Acetaldehyde | 75070 | Ethanal, ethyl aldehyde, acetic aldehyde | ||
| Acetic acid | 64197 | Glacial acetic acid, vinegar acid | ||
| Acetic anhydride | 108247 | Acetic oxide, acetyl oxide | ||
| Acetone cyanohydrin | 75865 | 2-methyllactonitrile, alpha-hydroxyisobutyronitrile | ||
| Acetyl bromide | 506967 | |||
| Acetyl chloride | 79367 | |||
| Acrolein | 107028 | 2-propenal, acrylic aldehyde, acrylaldehyde, acraldehyde | ||
| Acrylonitrile | 107131 | Cyanoethylene, Fumigrain, Ventox, propeneitrile, vinyl cyanide | ||
| Adipic acid | 124049 | Hexanedioic acid | ||
| Aldrin | 309002 | Octalene, HHDN | ||
| Allyl alcohol | 107186 | 2-propen-1-ol, 1-propenol-3, vinyl carbinol | ||
| Allyl chloride | 107051 | 3-chloropropene, 3-chloropropylene, Chlorallylene | ||
| Aluminum sulfate | 10043013 | Alum | ||
| Ammonia | 7664417 | |||
| Ammonium acetate | 631618 | Acetic acid ammonium, salt | ||
| Ammonium benzoate | 1863634 | |||
| Ammonium bicarbonate | 1066337 | Acid ammonium carbonate, ammonium hydrogen carbonate | ||
| Ammonium bichromate | 7789095 | |||
| Ammonium bifluoride | 1341497 | Acid ammonium fluoride, ammonium hydrogen fluoride | ||
| Ammonium bisulfite | 10192300 | |||
| Ammonium carbamate | 1111780 | Ammonium aminoformate | ||
| Ammonium carbonate | 506876 | |||
| Ammonium chloride | 12125029 | Ammonium muriate, sal ammoniac, salmiac, Amchlor | ||
| Ammonium chromate | 7788989 | |||
| Ammonium citrate dibasic | 3012655 | Diammonium citrate, citric acid diammonium salt | ||
| Ammonium fluoborate | 13826830 | Ammonium fluoroborate, ammonium borofluoride | ||
| Ammonium fluoride | 12125018 | Neutral ammonium fluoride | ||
| Ammonium hydroxide | 1336216 | |||
| Ammonium oxalate | 6009707 | |||
| 5972736 | ||||
| 14258492 | ||||
| Ammonium silicofluoride | 16919190 | Ammonium fluosilicate | ||
| Ammonium sulfamate | 7773060 | Ammate, AMS, ammonium amidosulfate | ||
| Ammonium sulfide | 12135761 | |||
| Ammonium sulfite | 10196040 | |||
| 10192300 | ||||
| Ammonium tartrate | 3164292 | Tartaric acid ammonium salt | ||
| 14307438 | ||||
| Ammonium thiocyanate | 1762954 | Ammonium rhodanide, ammonium sulfocyanate, ammonium sulfocyanide | ||
| Amly acetate | 628637 | Amylacetic ester | iso- | 123922 |
| Pear oil | sec- | 626380 | ||
| Banana oil | tert- | 625161 | ||
| Aniline | 62533 | Aniline oil, phenylamine, aminobenzene, aminophen, kyanol | ||
| Antimony pentachloride | 7647189 | |||
| Antimony potassium tartrate | 28300745 | Tartar emetic, tartrated antimony, tartarized antimony, potassium antimonyltartrate | ||
| Antimony tribromide | 7789619 | |||
| Antimony trichloride | 10025919 | Butter of antimony | ||
| Antimony trifluoride | 7783564 | Antimony fluoride | ||
| Antimony trioxide | 1309644 | Diantimony trioxide, flowers of antimony | ||
| Arsenic disulfide | 1303328 | Red arsenic sulfide | ||
| Arsenic pentoxide | 1303282 | Arsenic acid anhydride, arsenic oxide | ||
| Arsenic trichloride | 7784341 | Arsenic chloride, arsenious chloride, arsenous chloride, butter of arsenic | ||
| Arsenic trioxide | 1327533 | Arsenious acid, arsenious oxide, white arsenic | ||
| Arsenic trisulfide | 1303339 | Arsenious sulfide, yellow arsenic sulfide | ||
| Barium cyanide | 542621 | |||
| Benzene | 71432 | Cyclohexatriene, benzol | ||
| Benzoic acid | 65850 | Benzenecarboxylic acid, phenylformic acid, dracylic acid | ||
| Benzonitrile | 100470 | Phenyl cyanide, cyanobenzene | ||
| Benzoyl chloride | 98884 | Benzenecarbonyl chloride | ||
| Benzyl chloride | 100447 | |||
| Beryllium chloride | 7787475 | |||
| Beryllium fluoride | 7787497 | |||
| Beryllium nitrate | 7787555 | |||
| 13597994 | ||||
| Butyl acetate | 123864 | Acetic acid butyl ester | iso- | 110190 |
| sec- | 105464 | |||
| tert- | 540885 | |||
| Butylamine | 109739 | 1-aminobutane | iso- | 78819 |
| sec- | 513495 | |||
| sec- | 13952846 | |||
| tert- | 75649 | |||
| n/butyl phthalate | 84742 | 1.2-benzenedicarboxylic acid, dibutyl ester, dibutyl phthalate | ||
| Butyric acid | 107926 | Butanoic acid, ethylacetic acid | iso- | 79312 |
| Cadmium acetate | 543908 | |||
| Cadmium bromide | 7789426 | |||
| Cadmium chloride | 10108642 | |||
| Calcium arsenate | 7778441 | Tricalcium orthoarsenate | ||
| Calcium arsenite | 52740166 | |||
| Calcium carbide | 75207 | Carbide, acetylenogen | ||
| Calcium chromate | 13765190 | Calcium chrome yellow, geblin, yellow ultramarine | ||
| Calcium cyanide | 592018 | |||
| Calcium dodecylbenzenesulfonate | 26264062 | |||
| Calcium hypochlorite | 7778543 | |||
| Captan | 133062 | Orthocide-406, SR-406, Vancide-89 | ||
| Carbaryl | 63252 | Sevin | ||
| Carbofuran | 1563662 | Furadan | ||
| Carbon disulfide | 75150 | Carbon bisulfide, dithiocarbonic anhydride | ||
| Carbon tetrachloride | 56235 | Tetrachloromethane Perchloromethane | ||
| Chlordane | 57749 | Toxichlor, chlordan | ||
| Chlorine | 75003 | |||
| Chlorobenzene | 108907 | Monochlorobenzene, benzene chloride | ||
| Chloroform | 67663 | Trichloromethane | ||
| Chlorpyrifos | 2921882 | Dursban | ||
| Chlorosulfonic acid | 7790945 | Sulfuric chlorohydrin | ||
| Chromic acetate | 1066304 | |||
| Chromic acid | 11115745 | Chromic anhydride, chromium trioxide | ||
| Chromic sulfate | 10101538 | |||
| Chromous chloride | 10049055 | |||
| Cobaltous bromide | 7789437 | Cobalt bromide | ||
| Coabaltous formate | 544183 | Cobalt formate | ||
| Cobaltous sulfamate | 14017415 | Cobalt sulfamate | ||
| Coumaphos | 56724 | Co-Ral | ||
| Cresol | 1319773 | Cresylic acid | m- | 108394 |
| Hydroxytoluene | o- | 95487 | ||
| p- | 106445 | |||
| Crotonaldehyde | 4170303 | 2-butenal propylene aldelhyde | ||
| Cupric acetate | 142712 | Copper acetate, crystalized verdigris | ||
| Cupric acetoarsenite | 12002038 | Copper acetoarsenite, copper acetate arsenite, Paris green | ||
| Cupric chloride | 7447394 | Copper chloride | ||
| Cupric nitrate | 3251238 | Copper nitrate | ||
| Cupric oxalate | 5893663 | Copper oxalate | ||
| Cupric sulfate | 7758987 | Copper sulfate | ||
| Cupric sulfate, ammoniated | 10380297 | Ammoniated copper sulfate | ||
| Cupric tartrate | 815827 | Copper tartrate | ||
| Cyanogen chloride | 506774 | |||
| Cyclohexane | 110827 | Hexahydrobenzene, hexamethylene, hexanaphthene | ||
| 2,4-D acid | 94757 | 2,4-dichlorophenoxyacetic acid | ||
| 2,4-D ester | 94111 | 2,4-dichlorophenoxyacetic acid ester | ||
| 94791 | ||||
| 94804 | ||||
| 1320189 | ||||
| 1928387 | ||||
| 1928616 | ||||
| 1929733 | ||||
| 2971382 | ||||
| 25168267 | ||||
| 53467111 | ||||
| DDT | 50293 | p,p′-DDT | ||
| Diazinon | 333415 | Dipofene, Diazitol, Basudin, Spectracide | ||
| Dicamba | 1918009 | 2-methoxy-3,6-dichlorobenzoic acid | ||
| Dichlobenil | 1194656 | 2,6-dichlorobenzonitrile, 2,6-DBN | ||
| Dichlone | 117806 | Phygon, dichloronaphthoquinone | ||
| Dichlorobenzene | 25321226 | Di-chloricide | Ortho | 95501 |
| Paramoth (Para) | Para | 106467 | ||
| Dichloropropane | 26638197 | Propylene dichloride | 1,1 | 78999 |
| 1,2 | 78875 | |||
| 1,3 | 142289 | |||
| Dichloropropene | 26952238 | 1,3 | 542756 | |
| 2,3 | 78886 | |||
| Dichloropropene-dichloropropane (mixture) | 8003198 | D-D mixture Vidden D | ||
| 2,2-Dichloropropionic acid | 75990 | Dalapon | ||
| Dichlorvos | 62737 | 2,2-dichlorovinyl dimethyl phosphate, Vapona | ||
| Dicofol | 115322 | Di(p-chlorophenyl)-trichloromethylcarbinol, DTMC, dicofol | ||
| Dieldrin | 60571 | Alvit | ||
| Diethylamine | 109897 | |||
| Dimethylamine | 124403 | |||
| Dinitrobenzene (mixed) | 25154545 | Dinitrobenzol | m- | 99650 |
| o- | 528290 | |||
| p- | 100254 | |||
| Dinitrophenol | 51285 | Aldifen | (2,5-) | 329715 |
| (2,4-) | ||||
| (2,6-) | 573568 | |||
| Dinitrotoluene | 25321146 | DNT | 2,4 | 121142 |
| 2,6 | 606202 | |||
| 3,4 | 610399 | |||
| Diquat | 85007 | Aquacide | ||
| 2764729 | Dextrone, Reglone, Diquat dibromide | |||
| Disulfoton | 298044 | Di-syston | ||
| Diuron | 330541 | DCMU, DMU | ||
| Dodecylbenzenesulfonic acid | 27176870 | |||
| Endosulfan | 115297 | Thiodan | ||
| Endrin | 72208 | Mendrin, Compound 269 | ||
| Epichlorohydrin | 106898 | -chloropropylene oxide | ||
| Ethion | 563122 | Nialate, ethyl methylene, phosphorodithioate | ||
| Ethylbenzene | 100414 | Phenylethane | ||
| Ethylenediamine | 107153 | 1,2-diaminoethane | ||
| Ethylenediamine-tetraacetic acid (EDTA) | 60004 | Edetic acid, Havidote, (ethylenedinitrilo)-tetraacetic acid | ||
| Ethylene dibromide | 106934 | 1,2-dibromoethane acetylene dibromide sym-dibromoethylene | ||
| Ethylene dichloride | 107062 | 1,2-dichloroethane sym-bichloroethane | ||
| Ferric ammonium citrate | 1185575 | Ammonium ferric citrate | ||
| Ferric ammonium oxalate | 2944674 | Ammonium ferric oxalate | ||
| 55488874 | ||||
| Ferric chloride | 7705080 | Flores martis, iron trichloride | ||
| Ferric fluoride | 7783508 | |||
| Ferric nitrate | 10421484 | Iron nitrate | ||
| Ferric sulfate | 10028225 | Ferric persulfate, ferric sesquisulfate, ferric tersulfate | ||
| Ferrous ammonium sulfate | 10045893 | Mohr’s salt, iron ammonium sulfate | ||
| Ferrous chloride | 7758943 | Iron chloride, iron dichloride, iron protochloride | ||
| Ferrous sulfate | 7720787 | Green vitriol | ||
| 7782630 | Iron vitriol, iron sulfate, iron protosulfate | |||
| Formaldehyde | 50000 | Methyl aldehyde, methanal, formalin | ||
| Formic acid | 64186 | Methanoic acid | ||
| Fumaric acid | 110178 | Trans-butenedioic acid, trans-1,2-ethylenedicarboxylic acid, boletic acid, allomaleic acid | ||
| Furfural | 98011 | 2-furaldehyde, pyromucic aldehyde | ||
| Guthion | 86500 | Gusathion, azinphos-methyl | ||
| Heptachlor | 76448 | Velsicol-104, Drinox, Heptagran | ||
| Hexachlorocyclopentadiene | 77474 | Perchlorocyclopentadiene | ||
| Hydrochloric acid | 7647010 | Hydrogen chloride, muriatic acid | ||
| Hydrofluoric acid | 7664393 | Fluohydric acid | ||
| Hydrogen cyanide | 74908 | Hydrocyanic acid | ||
| Hydrogen sulfide | 7783064 | Hydrosulfuric acid sulfur hydride | ||
| Isoprene | 78795 | 2-methyl-1,3-butadiene | ||
| Isopropanolamine dodecylbenzenesulfonate | 42504461 | |||
| Kepone | 143500 | Chlordecone 1,1a,3,3a,4,5,5,5a,5b,6-decachlorooctahydro-1,3,4-metheno-2H-cyclobuta(cd)pentalen-2-one | ||
| Lead acetate | 301042 | Sugar of lead | ||
| Lead arsenate | 7784409 | |||
| 7645252 | ||||
| 10102484 | ||||
| Lead chloride | 7758954 | |||
| Lead fluoborate | 13814965 | Lead fluoroborate | ||
| Lead fluoride | 7783462 | Lead difluoride, plumbous fluoride | ||
| Lead iodide | 10101630 | |||
| Lead nitrate | 10099748 | |||
| Lead stearate | 7428480 | Stearic acid lead salt | ||
| 1072351 | ||||
| 52652592 | ||||
| Lead sulfate | 7446142 | |||
| Lead sulfide | 1314870 | Galena | ||
| Lead thiocyanate | 592870 | Lead sulfocyanate | ||
| Lindane | 58899 | Gamma-BHC, gamma-benzene hexachloride | ||
| Lithium chromate | 14307358 | |||
| Malathion | 121755 | Phospothion | ||
| Maleic acid | 110167 | Cis-butenedioic acid, cis-1,2-ethylenedicarboxylic acid, toxilic acid | ||
| Maleic anhydride | 108316 | 2,5-furandione, cis-butenedioic anhydride, toxilic anhydride | ||
| Mercaptodimethur | 203657 | Mesurol | ||
| Mercuric cyanide | 592041 | Mercury cyanide | ||
| Mercuric nitrate | 10045940 | Mercury nitrate, mercury pernitrate | ||
| Mercuric sulfate | 7783359 | Mercury sulfate, mercury persulfate | ||
| Mercuric thiocyanate | 592858 | Mercury thiocyanate, mercuric sulfocyanate, mercuric sulfocyanide | ||
| Mercurous nitrate | 7782867 | |||
| 10415755 | Mercury protonitrate | |||
| Methoxychlor | 72435 | DMDT, methoxy-DDT | ||
| Methyl mercaptan | 74931 | Methanethiol, mercaptomethane, methyl sulfhydrate, thiomethyl alcohol | ||
| Methyl methacrylate | 80626 | Methacrylic acid methyl ester, methyl-2-methyl-2-propenoate | ||
| Methyl parathion | 298000 | Nitrox-80 | ||
| Mevinphos | 7786347 | Phosdrin | ||
| Mexacarbate | 315184 | Zectran | ||
| Monoethylamine | 75047 | Ethylamine, aminoethane | ||
| Monomethylamine | 74895 | Methylamine, aminomethane | ||
| Naled | 300765 | Dibrom | ||
| Naphthalene | 91203 | White tar, tar camphor, naphthalin | ||
| Naphthenic acid | 1338245 | Cyclohexanecarboxylic acid, hexahydrobenzoic acid | ||
| Nickel ammonium sulfate | 15699180 | Ammonium nickel sulfate | ||
| Nickel chloride | 37211055 | Nickelous chloride | ||
| 7718549 | ||||
| Nickel hydroxide | 12054487 | Nickelous hydroxide | ||
| Nickel nitrate | 14216752 | |||
| Nickel sulfate | 7786814 | Nickelous sulfate | ||
| Nitric acid | 7697372 | Aqua fortis | ||
| Nitrobenzene | 98953 | Nitrobenzol, oil of mirbane | ||
| Nitrogen dioxide | 10102440 | Nitrogen tetraoxide | ||
| Nitrophenol (mixed) | 25154556 | Mononitrophenol | m- | 554847 |
| o- | 88755 | |||
| p- | 100027 | |||
| Nitrotoluene | 1321126 | Ortho | 88722 | |
| Meta | 99081 | |||
| Para | 99990 | |||
| Paraformaldehyde | 30525894 | Paraform, Formagene, Triformol, polymerized formaldehyde, polyoxymethylene | ||
| Parathion | 56382 | DNTP, Niran | ||
| Pentachlorophenol | 87865 | PCP, Penta | ||
| Phenol | 108952 | Carbolic acid, phenyl hydroxide, hydroxybenzene, oxybenzene | ||
| Phosgene | 75445 | Diphosgene, carbonyl chloride, chloroformyl chloride | ||
| Phosphoric acid | 7664382 | Orthophosphoric acid | ||
| Phosphorus | 7723140 | Black phosphorus, red phosphorus, white phosphorus, yellow phosphorus | ||
| Phosphorus oxychloride | 10025873 | Phosphoryl chloride, phosphorus chloride | ||
| Phosphorus pentasulfide | 1314803 | Phosphoric sulfide, thiophosphoric anhydride, phosphorus persulfide | ||
| Phosphorus trichloride | 7719122 | Phosphorous chloride | ||
| Polychorinated biphenyls | 1336363 | PCB, Aroclor, polychlorinated diphenyls | ||
| Potassium arsenate | 7784410 | |||
| Potassium arsenite | 10124502 | Potassium metaarsenite | ||
| Potassium bichromate | 7778509 | Potassium dichromate | ||
| Potassium chromate | 7789006 | |||
| Potassium cyanide | 151508 | |||
| Potassium hydroxide | 1310583 | Potassium hydrate, caustic potash, potassa | ||
| Potassium permanganate | 7722647 | Chameleon mineral | ||
| Propargite | 2312358 | Omite | ||
| Propionic acid | 79094 | Propanoic acid, methylacetic acid, ethylformic acid | ||
| Propionic anhydride | 123626 | Propanoic anhydride, methylacetic anhydride | ||
| Propylene oxide | 75569 | Propene oxide | ||
| Pyrethrins | 121299 | Pyrethrin I | ||
| 121211 | Pyrethrin II | |||
| Quinoline | 91225 | 1-benzazine, benzo(b)pyridine, leuocoline, chinoleine, leucol | ||
| Resorcinol | 108463 | Resorcin, 1,3-benzenediol, meta-dihydroxybenzene | ||
| Selenium oxide | 7446084 | Selenium dioxide | ||
| Silver nitrate | 7761888 | Nitric acid silver (1 + ) salt lunar caustic | ||
| Sodium | 7440235 | Natrium | ||
| Sodium arsenate | 7631892 | Disodium arsenate | ||
| Sodium arsenite | 7784465 | Sodium metaarsenite | ||
| Sodium bichromate | 10588019 | Sodium dichromate | ||
| Sodium bifluoride | 1333831 | |||
| Sodium bisulfite | 7631905 | Sodium acid sulfite, sodium hydrogen sulfite | ||
| Sodium chromate | 7775113 | |||
| Sodium cyanide | 143339 | |||
| Sodium dodecylbenzene-sulfonate | 25155300 | |||
| Sodium fluoride | 7681494 | Villiaumite | ||
| Sodium hydrosulfide | 16721805 | Sodium hydrogen sulfide | ||
| Sodium hydroxide | 1310732 | Caustic soda, soda lye, sodium hydrate | ||
| Sodium hypochlorite | 7681529 | Bleach | ||
| 10022705 | ||||
| Sodium methylate | 124414 | Sodium methoxide | ||
| Sodium nitrite | 7632000 | |||
| Sodium phosphate, dibasic | 7558794 | |||
| 10039324 | ||||
| 10140655 | ||||
| Sodium phosphate, tribasic | 7601549 | |||
| 10101890 | ||||
| 10361894 | ||||
| Sodium selenite | 10102188 | |||
| 7782823 | ||||
| Strontium chromate | 7789062 | |||
| Strychnine | 57249 | |||
| Styrene | 100425 | Vinylbenzene, phenylethylene, styrol, styrolene, cinnamene, cinnamol | ||
| Sulfuric acid | 7664939 | Oil of vitriol, oleum | ||
| Sulfur monochloride | 12771083 | Sulfur chloride | ||
| 2,4,5-T acid | 93765 | 2,4,5-trichlorophenoxyacetic acid | ||
| 2,4,5-T amines | 6369966 | Acetic acid (2,4,5-trichlorophenoxy)-compound with N,N-dimethylmethanamine (1:1) | ||
| 6369977 | Acetic acid (2,4,5-trichlorophenoxy)-compound with N-methylmethanamine (1:1) | |||
| 1319728 | Acetic acid (2,4,5-trichlorophenoxy)-compound with 1-amino-2-propanol (1:1) | |||
| 3813147 | Acetic acid (2,4,5-trichlorophenoxy)-compound with 2,2’2”-nitrilotris [ethanol] (1:1) | |||
| 2,4,5-T esters | 2545597 | 2,4,5-trichlorophenoxyacetic esters | ||
| 93798 | ||||
| 61792072 | ||||
| 1928478 | ||||
| 25168154 | ||||
| 2,4,5-T salts | 13560991 | Acetic acid (2,4,5-trichlorophenoxy)-sodium salt | ||
| TDE | 72548 | DDD | ||
| 2,4,5-TP acid | 93721 | Propanoic acid 2-(2,4,5-trichlorophenoxy) | ||
| 2,4,5-TP esters | 32534955 | Propanoic acid, 2-(2,4,5-trichlorophenoxy)-, isooctyl ester | ||
| Tetraethyl lead | 78002 | Lead tetraethyl, TEL | ||
| Tetraethyl pyrophosphate | 107493 | TEPP | ||
| Thallium sulfate | 10031591 | |||
| 7446186 | ||||
| Toluene | 108883 | Toluol, methylbenzene, phenylmethane, Methacide | ||
| Toxaphene | 8001352 | Camphechlor | ||
| Trichlorfon | 52686 | Dipterex Dylox | ||
| Trichlorethylene | 79016 | Ethylene trichloride | ||
| Trichlorophenol | 25167822 | Collunosol, Dowicide 2 or 2S, Omal, Phenachlor | (2,3,4-) (2,3,5-) (2,3,6-) (2,4,5-) (2,4,6-) (3,4,5-) | 15950660 933788 933755 95954 88062 609198 |
| Triethanolamine dodecylbenzenesulfonate | 27323417 | |||
| Triethylamine | 121448 | |||
| Trimethylamine | 75503 | TMA | ||
| Uranyl acetate | 541093 | |||
| Uranyl nitrate | 10102064 | |||
| 36478769 | ||||
| Vanadium pentoxide | 1314621 | Vanadic anhydride, vanadic acid anhydride | ||
| Vanadyl sulfate | 27774136 | Vanadic sulfate, vanadium sulfate | ||
| Vinyl acetate | 108054 | Acetic acid ethylene ether | ||
| Vinylidene chloride | 75354 | 1,1-dichlorethylene | ||
| 1,1-dichloroethene | ||||
| Xylene (mixed) | 1330207 | Dimethylbenzene | m- | 108383 |
| Xylol | o- | 95476 | ||
| p- | 106423 | |||
| Xylenol | 1300716 | Dimethylphenol, hydroxydimethylbenzene | ||
| Zinc acetate | 557346 | |||
| Zinc ammonium chloride | 14639975 | |||
| 14639986 | ||||
| 52628258 | ||||
| Zinc borate | 1332076 | |||
| Zinc bromide | 7699458 | |||
| Zinc carbonate | 3486359 | |||
| Zinc chloride | 7646857 | Butter of zinc | ||
| Zinc cyanide | 557211 | |||
| Zinc fluoride | 7783495 | |||
| Zinc formate | 557415 | |||
| Zinc hydrosulfite | 7779864 | |||
| Zinc nitrate | 7779886 | |||
| Zinc phenolsulfonate | 127822 | Zinc sulfocarbolate | ||
| Zinc phosphide | 1314847 | |||
| Zinc silicofluoride | 16871719 | Zinc fluosilicate | ||
| Zinc sulfate | 7733020 | White vitriol, zinc vitriol, white copperas | ||
| Zirconium nitrate | 13746899 | |||
| Zirconium potassium fluoride | 16923958 | |||
| Zirconium sulfate | 14644612 | Disulfatozirconic acid | ||
| Zirconium tetrachloride | 10026116 |
Table 116.4B – List of Hazardous Substances by CAS Number
| CAS No. | Common name |
|---|---|
| 50000 | Formaldehyde |
| 50293 | DDT |
| 51285 | 2,4-Dinitrophenol |
| 52686 | Trichlorfon |
| 56382 | Parathion |
| 56724 | Coumaphos |
| 57249 | Strychnine |
| 57749 | Chlordane |
| 58899 | Lindane |
| 60004 | Ethylenediaminetetraacetic |
| acid (EDTA) | |
| 60571 | Dieldrin |
| 62533 | Aniline |
| 62737 | Dichlorvos |
| 63252 | Carbaryl |
| 64186 | Formic acid |
| 64197 | Acetic acid |
| 65850 | Benzoic acid |
| 67663 | Chloroform |
| 71432 | Benzene |
| 72208 | Endrin |
| 72435 | Methoxychlor |
| 72548 | TDE |
| 74895 | Monomethylamine |
| 74908 | Hydrogen cyanide |
| 74931 | Methyl mercaptan |
| 75047 | Monoethylamine |
| 75070 | Acetaldehyde |
| 75150 | Carbon disulfide |
| 75207 | Calcium carbide |
| 75445 | Phosgene |
| 75503 | Trimethylamine |
| 75649 | tert-Butylamine |
| 75865 | Acetone cyanohydrin |
| 75990 | 2,2-Dichloropropionic acid |
| 76448 | Heptachlor |
| 78002 | Tetraethyl lead |
| 78795 | Isoprene |
| 78819 | iso-Butylamine |
| 79094 | Propionic acid |
| 79312 | iso-Butyric acid |
| 79367 | Acetyl chloride |
| 80626 | Methyl methacrylate |
| 85007 | Diquat |
| 86500 | Guthion |
| 87865 | Pentachlorophenol |
| 88755 | o-Nitrophenol |
| 91203 | Naphthalene |
| 91225 | Quinoline |
| 93765 | 2,4,5-T acid |
| 93798 | 2,4,5-T ester |
| 94111 | 2,4-D ester |
| 94757 | 2,4-D acid |
| 94791 | 2,4-D ester |
| 94804 | 2,4-D Butyl ester |
| 95476 | o-Xylene |
| 95487 | o-Cresol |
| 98011 | Furfural |
| 98884 | Benzoyl chloride |
| 98953 | Nitrobenzene |
| 99650 | m-Dinitrobenzene |
| 100027 | p-Nitrophenol |
| 100254 | p-Dinitrobenzene |
| 100414 | Ethylbenzene |
| 100425 | Styrene |
| 100447 | Benzyl chloride |
| 100470 | Benzonitrile |
| 105464 | sec-Butyl acetate |
| 106423 | p-Xylene |
| 106445 | p-Cresol |
| 107028 | Acrolein |
| 107051 | Allyl chloride |
| 107131 | Acrylonitrile |
| 107153 | Ethylenediamine |
| 107186 | Allyl alcohol |
| 107493 | Tetraethyl pyrophosphate |
| 107926 | n-Butyric acid |
| 108054 | Vinyl acetate |
| 108247 | Acetic anhydride |
| 108316 | Maleic anhydride |
| 108383 | m-Xylene |
| 108394 | m-Cresol |
| 108463 | Resorcinol |
| 108883 | Toluene |
| 108907 | Chlorobenzene |
| 108952 | Phenol |
| 109739 | n-Butylamine |
| 109897 | Diethylamine |
| 110167 | Maleic acid |
| 110178 | Fumaric acid |
| 110190 | iso-Butyl acetate |
| 110827 | Cyclohexane |
| 115297 | Endosulfan |
| 115322 | Dicofol |
| 117806 | Dichlone |
| 121211 | Pyrethrin |
| 121299 | Pyrethrin |
| 121448 | Triethylamine |
| 121755 | Malathion |
| 123626 | Propionic anhydride |
| 123864 | n-Butyl acetate |
| 123922 | iso-Amyl acetate |
| 124403 | Dimethylamine |
| 124414 | Sodium methylate |
| 127822 | Zinc phenolsulfonate |
| 133062 | Captan |
| 142712 | Cupric acetate |
| 143339 | Sodium cyanide |
| 151508 | Potassium cyanide |
| 298000 | Methyl parathion |
| 298044 | Disulfoton |
| 300765 | Naled |
| 301042 | Lead acetate |
| 309002 | Aldrin |
| 315184 | Mexacarbate |
| 329715 | 2,5-Dinitrophenol |
| 330541 | Diuron |
| 333415 | Diazinon |
| 506774 | Cyanogen chloride |
| 506876 | Ammonium carbonate |
| 506967 | Acetyl bromide |
| 513495 | sec-Butylamine |
| 528290 | o-Dinitrobenzene |
| 540885 | tert-Butyl acetate |
| 541093 | Uranyl acetate |
| 542621 | Barium cyanide |
| 543908 | Cadmium acetate |
| 544183 | Cobaltous formate |
| 554847 | m-Nitrophenol |
| 557211 | Zinc cyanide |
| 557346 | Zinc acetate |
| 557415 | Zinc formate |
| 563122 | Ethion |
| 573568 | 2,6-Dinitrophenol |
| 592018 | Calcium cyanide |
| 592041 | Mercuric cyanide |
| 592858 | Mercuric thiocyanate |
| 592870 | Lead thiocyanate |
| 625161 | tert-Amyl acetate |
| 626380 | sec-Amyl acetate |
| 628637 | n-Amyl acetate |
| 631618 | Ammonium acetate |
| 815827 | Cupric tartrate |
| 1066304 | Chromic acetate |
| 1066337 | Ammonium bicarbonate |
| 1072351 | Lead stearate |
| 1111780 | Ammonium carbamate |
| 1185575 | Ferric ammonium citrate |
| 1194656 | Dichlobenil |
| 1300716 | Xylenol |
| 1303282 | Arsenic pentoxide |
| 1303328 | Arsenic disulfide |
| 1303339 | Arsenic trisulfide |
| 1309644 | Antimony trioxide |
| 1310583 | Potassium hydroxide |
| 1310732 | Sodium hydroxide |
| 1314621 | Vanadium pentoxide |
| 1314803 | Phosphorus pentasulfide |
| 1314847 | Zinc phosphide |
| 1314870 | Lead sulfide |
| 1319773 | Cresol (mixed) |
| 1320189 | 2,4-D ester |
| 1327533 | Arsenic trioxide |
| 1330207 | Xylene |
| 1332076 | Zinc borate |
| 1333831 | Sodium bifluoride |
| 1336216 | Ammonium hydroxide |
| 1336363 | Polychlorinated biphenyls |
| 1338245 | Naphthenic acid |
| 1341497 | Ammonium bifluoride |
| 1762954 | Ammonium thiocyanate |
| 1863634 | Ammonium benzoate |
| 1918009 | Dicamba |
| 1928387 | 2,4-D esters |
| 1928478 | 2,4,5-T ester |
| 1928616 | 2,4-D ester |
| 1929733 | 2,4-D ester |
| 2545597 | 2,4,5-T ester |
| 2764729 | Diquat |
| 2921882 | Chlorpyrifos |
| 2944674 | Ferric ammonium oxalate |
| 2971382 | 2,4-D ester |
| 3012655 | Ammonium citrate, dibasic |
| 3164292 | Ammonium tartrate |
| 3251238 | Cupric nitrate |
| 3486359 | Zinc carbonate |
| 5893663 | Cupric oxalate |
| 5972736 | Ammonium oxalate |
| 6009707 | Ammonium oxalate |
| 6369966 | 2,4,5-T ester |
| 7428480 | Lead stearate |
| 7440235 | Sodium |
| 7446084 | Selenium oxide |
| 7446142 | Lead sulfate |
| 7447394 | Cupric chloride |
| 7558794 | Sodium phosphate, dibasic |
| 7601549 | Sodium phosphate, tribasic |
| 7631892 | Sodium arsenate |
| 7631905 | Sodium bisulfite |
| 7632000 | Sodium nitrite |
| 7645252 | Lead arsenate |
| 7646857 | Zinc chloride |
| 7647010 | Hydrochloric acid |
| 7647189 | Antimony pentachloride |
| 7664382 | Phosphoric acid |
| 7664393 | Hydrofluoric acid |
| 7664417 | Ammonia |
| 7664939 | Sulfuric acid |
| 7681494 | Sodium fluoride |
| 7681529 | Sodium hypochlorite |
| 7697372 | Nitric acid |
| 7699458 | Zinc bromide |
| 7705080 | Ferric chloride |
| 7718549 | Nickel chloride |
| 7719122 | Phosphorus trichloride |
| 7720787 | Ferrous sulfate |
| 7722647 | Potassium permanganate |
| 7723140 | Phosphorus |
| 7733020 | Zinc sulfate |
| 7758943 | Ferrous chloride |
| 7758954 | Lead chloride |
| 7758987 | Cupric sulfate |
| 7773060 | Ammonium sulfamate |
| 7775113 | Sodium chromate |
| 7778441 | Calcium arsenate |
| 7778509 | Potassium bichromate |
| 7778543 | Calcium hypochlorite |
| 7779864 | Zinc hydrosulfite |
| 7779886 | Zinc nitrate |
| 7782505 | Chlorine |
| 7782630 | Ferrous sulfate |
| 7782823 | Sodium selenite |
| 7782867 | Mercurous nitrate |
| 7783359 | Mercuric sulfate |
| 7783462 | Lead fluoride |
| 7783495 | Zinc fluoride |
| 7783508 | Ferric fluoride |
| 7783564 | Antimony trifluoride |
| 7784341 | Arsenic trichloride |
| 7784409 | Lead arsenate |
| 7784410 | Potassium arsenate |
| 7784465 | Sodium arsenite |
| 7786347 | Mevinphos |
| 7786814 | Nickel sulfate |
| 7787475 | Beryllium chloride |
| 7787497 | Beryllium fluoride |
| 7787555 | Beryllium nitrate |
| 7788989 | Ammonium chromate |
| 7789006 | Potassium chromate |
| 7789062 | Strontium chromate |
| 7789095 | Ammonium bichromate |
| 7789426 | Cadmium bromide |
| 7789437 | Cobaltous bromide |
| 7789619 | Antimony tribromide |
| 7790945 | Chlorosulfonic acid |
| 8001352 | Toxaphene |
| 10022705 | Sodium hypochlorite |
| 10025873 | Phosphorus oxychloride |
| 10025919 | Antimony trichloride |
| 10026116 | Zirconium tetrachloride |
| 10028225 | Ferric sulfate |
| 10028247 | Sodium phosphate, dibasic |
| 10039324 | Sodium phosphate, dibasic |
| 10043013 | Aluminum sulfate |
| 10045893 | Ferrous ammonium sulfate |
| 10045940 | Mercuric nitrate |
| 10049055 | Chromous chloride |
| 10099748 | Lead nitrate |
| 10101538 | Chromic sulfate |
| 10101630 | Lead iodide |
| 10101890 | Sodium phosphate, tribasic |
| 10102064 | Uranyl nitrate |
| 10102188 | Sodium selenite |
| 10102440 | Nitrogen dioxide |
| 10102484 | Lead arsenate |
| 10108642 | Cadmium chloride |
| 10124502 | Potassium arsenite |
| 10140655 | Sodium phosphate, dibasic |
| 10192300 | Ammonium bisulfite |
| 10196040 | Ammonium sulfite |
| 10361894 | Sodium phosphate, tribasic |
| 10380297 | Cupric sulfate, ammoniated |
| 10415755 | Mercurous nitrate |
| 10421484 | Ferric nitrate |
| 10588019 | Sodium bichromate |
| 11115745 | Chromic acid |
| 12002038 | Cupric acetoarsenite |
| 12054487 | Nickel hydroxide |
| 12125018 | Ammonium fluoride |
| 12125029 | Ammonium chloride |
| 12135761 | Ammonium sulfide |
| 12771083 | Sulfur chloride |
| 13597994 | Beryllium nitrate |
| 13746899 | Zirconium nitrate |
| 13765190 | Calcium chromate |
| 13814965 | Lead fluoborate |
| 13826830 | Ammonium fluoborate |
| 13952846 | sec-Butylamine |
| 14017415 | Cobaltous sulfamate |
| 14216752 | Nickel nitrate |
| 14258492 | Ammonium oxalate |
| 14307358 | Lithium chromate |
| 14307438 | Ammonium tartrate |
| 14639975 | Zinc ammonium chloride |
| 14639986 | Zinc ammonium chloride |
| 14644612 | Zirconium sulfate |
| 15699180 | Nickel ammonium sulfate |
| 16721805 | Sodium hydrosulfide |
| 16871719 | Zinc silicofluoride |
| 16919190 | Ammonium silicofluoride |
| 16923958 | Zirconium potassium fluoride |
| 25154545 | Dinitrobenzene |
| 25154556 | Nitrophenol |
| 25155300 | Sodium dodecylbenzenesulfonate |
| 25167822 | Trichlorophenol |
| 25168154 | 2,4,5-T ester |
| 25168267 | 2,4-D ester |
| 26264062 | Calcium dodecylbenzenesulfonate |
| 27176870 | Dodecylbenzenesulfonic acid |
| 27323417 | Triethanolamine dodecylbenzenesulfonate |
| 27774136 | Vanadyl sulfate |
| 28300745 | Antimony potassium tartrate |
| 30525894 | Paraformaldehyde |
| 36478769 | Uranyl nitrate |
| 37211055 | Nickel chloride |
| 42504461 | Dodecylbenzenesulfonate isopropanolamine |
| 52628258 | Zinc ammonium chloride |
| 52740166 | Calcium arsenite |
| 53467111 | 2,4-D ester |
| 55488874 | Ferric ammonium oxalate |
| 61792072 | 2,4,5-T ester |
PART 117 – DETERMINATION OF REPORTABLE QUANTITIES FOR HAZARDOUS SUBSTANCES
Subpart A – General Provisions
§ 117.1 Definitions.
As used in this part, all terms shall have the meanings stated in 40 CFR part 116.
(a) Reportable quantities means quantities that may be harmful as set forth in § 117.3, the discharge of which is a violation of section 311(b)(3) and requires notice as set forth in § 117.21.
(b) Administrator means the Administrator of the Environmental Protection Agency (“EPA”).
(c) Mobile source means any vehicle, rolling stock, or other means of transportation which contains or carries a reportable quantity of a hazardous substance.
(d) Public record means the NPDES permit application or the NPDES permit itself and the materials comprising the administrative record for the permit decision specified in § 124.18 of this chapter.
(e) National Pretreatment Standard or Pretreatment Standard means any regulation containing pollutant discharge limits promulgated by the EPA in accordance with section 307 (b) and (c) of the Act, which applies to industrial users of a publicly owned treatment works. It further means any State or local pretreatment requirement applicable to a discharge and which is incorporated into a permit issued to a publicly owned treatment works under section 402 of the Act.
(f) Publicly Owned Treatment Works or POTW means a treatment works as defined by section 212 of the Act, which is owned by a State or municipality (as defined by section 502(4) of the Act). This definition includes any sewers that convey wastewater to such a treatment works, but does not include pipes, sewers or other conveyances not connected to a facility providing treatment. The term also means the municipality as defined in section 502(4) of the Act, which has jurisdiction over the indirect discharges to and the discharges from such a treatment works.
(g) Remove or removal refers to removal of the oil or hazardous substances from the water and shoreline or the taking of such other actions as may be necessary to minimize or mitigate damage to the public health or welfare, including, but not limited to, fish, shellfish, wildlife, and public and private property, shorelines, and beaches.
(h) Contiguous zone means the entire zone established by the United States under Article 24 of the Convention on the Territorial Sea and Contiguous Zone.
(i) Navigable waters means “waters of the United States, including the territorial seas,” as defined in § 120.2 of this chapter.
(j) Process waste water means any water which, during manufacturing or processing, comes into direct contact with or results from the production or use of any raw material, intermediate product, finished product, byproduct, or waste product.
§ 117.2 Abbreviations.
NPDES equals National Pollutant Discharge Elimination System. RQ equals reportable quantity.
§ 117.3 Determination of reportable quantities.
Each substance in Table 117.3 that is listed in Table 302.4, 40 CFR part 302, is assigned the reportable quantity listed in Table 302.4 for that substance.
The first number under the column headed “RQ” is the reportable quantity in pounds. The number in parentheses is the metric equivalent in kilograms. For convenience, the table contains a column headed “Category” which lists the code letters “X”, “A”, “B”, “C”, and “D” associated with reportable quantities of 1, 10, 100, 1000, and 5000 pounds, respectively.
Table 117.3 – Reportable Quantities of Hazardous Substances Designated Pursuant to Section 311 of the Clean Water Act
| Material | Category | RQ in pounds (kilograms) |
|---|---|---|
| Acetaldehyde | C | 1,000 (454) |
| Acetic acid | D | 5,000 (2,270) |
| Acetic anhydride | D | 5,000 (2,270) |
| Acetone cyanohydrin | A | 10 (4.54) |
| Acetyl bromide | D | 5,000 (2,270) |
| Acetyl chloride | D | 5,000 (2,270) |
| Acrolein | X | 1 (0.454) |
| Acrylonitrile | B | 100 (45.4) |
| Adipic acid | D | 5,000 (2,270) |
| Aldrin | X | 1 (0.454) |
| Allyl alcohol | B | 100 (45.4) |
| Allyl chloride | C | 1,000 (454) |
| Aluminum sulfate | D | 5,000 (2,270) |
| Ammonia | B | 100 (45.4) |
| Ammonium acetate | D | 5,000 (2,270) |
| Ammonium benzoate | D | 5,000 (2,270) |
| Ammonium bicarbonate | D | 5,000 (2,270) |
| Ammonium bichromate | A | 10 (4.54) |
| Ammonium bifluoride | B | 100 (45.4) |
| Ammonium bisulfite | D | 5,000 (2,270) |
| Ammonium carbamate | D | 5,000 (2,270) |
| Ammonium carbonate | D | 5,000 (2,270) |
| Ammonium chloride | D | 5,000 (2,270) |
| Ammonium chromate | A | 10 (4.54) |
| Ammonium citrate dibasic | D | 5,000 (2,270) |
| Ammonium fluoborate | D | 5,000 (2,270) |
| Ammonium fluoride | B | 100 (45.4) |
| Ammonium hydroxide | C | 1,000 (454) |
| Ammonium oxalate | D | 5,000 (2,270) |
| Ammonium silicofluoride | C | 1,000 (454) |
| Ammonium sulfamate | D | 5,000 (2,270) |
| Ammonium sulfide | B | 100 (45.4) |
| Ammonium sulfite | D | 5,000 (2,270) |
| Ammonium tartrate | D | 5,000 (2,270) |
| Ammonium thiocyanate | D | 5,000 (2,270) |
| Amyl acetate | D | 5,000 (2,270) |
| Aniline | D | 5,000 (2,270) |
| Antimony pentachloride | C | 1,000 (454) |
| Antimony potassium tartrate | B | 100 (45.4) |
| Antimony tribromide | C | 1,000 (454) |
| Antimony trichloride | C | 1,000 (454) |
| Antimony trifluoride | C | 1,000 (454) |
| Antimony trioxide | C | 1,000 (454) |
| Arsenic disulfide | X | 1 (0.454) |
| Arsenic pentoxide | X | 1 (0.454) |
| Arsenic trichloride | X | 1 (0.454) |
| Arsenic trioxide | X | 1 (0.454) |
| Arsenic trisulfide | X | 1 (0.454) |
| Barium cyanide | A | 10 (4.54) |
| Benzene | A | 10 (4.54) |
| Benzoic acid | D | 5,000 (2,270) |
| Benzonitrile | D | 5,000 (2,270) |
| Benzoyl chloride | C | 1,000 (454) |
| Benzyl chloride | B | 100 (45.4) |
| Beryllium chloride | X | 1 (0.454) |
| Beryllium fluoride | X | 1 (0.454) |
| Beryllium nitrate | X | 1 (0.454) |
| Butyl acetate | D | 5,000 (2,270) |
| Butylamine | C | 1,000 (454) |
| n-Butyl phthalate | A | 10 (4.54) |
| Butyric acid | D | 5,000 (2,270) |
| Cadmium acetate | A | 10 (4.54) |
| Cadmium bromide | A | 10 (4.54) |
| Cadmium chloride | A | 10 (4.54) |
| Calcium arsenate | X | 1 (0.454) |
| Calcium arsenite | X | 1 (0.454) |
| Calcium carbide | A | 10 (4.54) |
| Calcium chromate | A | 10 (4.54) |
| Calcium cyanide | A | 10 (4.54) |
| Calcium dodecylbenzenesulfonate | C | 1,000 (454) |
| Calcium hypochlorite | A | 10 (4.54) |
| Captan | A | 10 (4.54) |
| Carbaryl | B | 100 (45.4) |
| Carbofuran | A | 10 (4.54) |
| Carbon disulfide | B | 100 (45.4) |
| Carbon tetrachloride | A | 10 (4.54) |
| Chlordane | X | 1 (0.454) |
| Chlorine | A | 10 (4.54) |
| Chlorobenzene | B | 100 (45.4) |
| Chloroform | A | 10 (4.54) |
| Chlorosulfonic acid | C | 1,000 (454) |
| Chlorpyrifos | X | 1 (0.454) |
| Chromic acetate | C | 1,000 (454) |
| Chromic acid | A | 10 (4.54) |
| Chromic sulfate | C | 1,000 (454) |
| Chromous chloride | C | 1,000 (454) |
| Cobaltous bromide | C | 1,000 (454) |
| Cobaltous formate | C | 1,000 (454) |
| Cobaltous sulfamate | C | 1,000 (454) |
| Coumaphos | A | 10 (4.54) |
| Cresol | B | 100 (45.4) |
| Crotonaldehyde | B | 100 (45.4) |
| Cupric acetate | B | 100 (45.4) |
| Cupric acetoarsenite | X | 1 (0.454) |
| Cupric chloride | A | 10 (4.54) |
| Cupric nitrate | B | 100 (45.4) |
| Cupric oxalate | B | 100 (45.4) |
| Cupric sulfate | A | 10 (4.54) |
| Cupric sulfate, ammoniated | B | 100 (45.4) |
| Cupric tartrate | B | 100 (45.4) |
| Cyanogen chloride | A | 10 (4.54) |
| Cyclohexane | C | 1,000 (454) |
| 2,4-D Acid | B | 100 (45.4) |
| 2,4-D Esters | B | 100 (45.4) |
| DDT | X | 1 (0.454) |
| Diazinon | X | 1 (0.454) |
| Dicamba | C | 1,000 (454) |
| Dichlobenil | B | 100 (45.4) |
| Dichlone | X | 1 (0.454) |
| Dichlorobenzene | B | 100 (45.4) |
| Dichloropropane | C | 1,000 (454) |
| Dichloropropene | B | 100 (45.4) |
| Dichloropropene-Dichloropropane (mixture) | B | 100 (45.4) |
| 2,2-Dichloropropionic acid | D | 5,000 (2,270) |
| Dichlorvos | A | 10 (4.54) |
| Dicofol | A | 10 (4.54) |
| Dieldrin | X | 1 (0.454) |
| Diethylamine | B | 100 (45.4) |
| Dimethylamine | C | 1,000 (454) |
| Dinitrobenzene (mixed) | B | 100 (45.4) |
| Dinitrophenol | A | 10 (45.4) |
| Dinitrotoluene | A | 10 (4.54) |
| Diquat | C | 1,000 (454) |
| Disulfoton | X | 1 (0.454) |
| Diuron | B | 100 (45.4) |
| Dodecylbenzenesulfonic acid | C | 1,000 (454) |
| Endosulfan | X | 1 (0.454) |
| Endrin | X | 1 (0.454) |
| Epichlorohydrin | B | 100 (45.4) |
| Ethion | A | 10 (4.54) |
| Ethylbenzene | C | 1,000 (454) |
| Ethylenediamine | D | 5,000 (2,270) |
| Ethylenediamine-tetraacetic acid (EDTA) | D | 5,000 (2,270) |
| Ethylene dibromide | X | 1 (0.454) |
| Ethylene dichloride | B | 100 (45.4) |
| Ferric ammonium citrate | C | 1,000 (454) |
| Ferric ammonium oxalate | C | 1,000 (454) |
| Ferric chloride | C | 1,000 (454) |
| Ferric fluoride | B | 100 (45.4) |
| Ferric nitrate | C | 1,000 (454) |
| Ferric sulfate | C | 1,000 (454) |
| Ferrous ammonium sulfate | C | 1,000 (454) |
| Ferrous chloride | B | 100 (45.4) |
| Ferrous sulfate | C | 1,000 (454) |
| Formaldehyde | B | 100 (45.4) |
| Formic acid | D | 5,000 (2,270) |
| Fumaric acid | D | 5,000 (2,270) |
| Furfural | D | 5,000 (2,270) |
| Guthion | X | 1 (0.454) |
| Heptachlor | X | 1 (0.454) |
| Hexachlorocyclopentadiene | A | 10 (4.54) |
| Hydrochloric acid | D | 5,000 (2,270) |
| Hydrofluoric acid | B | 100 (45.4) |
| Hydrogen cyanide | A | 10 (4.54) |
| Hydrogen sulfide | B | 100 (45.4) |
| Isoprene | B | 100 (45.4) |
| Isopropanolamine dodecylbenzenesulfonate | C | 1,000 (454) |
| Kepone | X | 1 (0.454) |
| Lead acetate | A | 10 (4.54) |
| Lead arsenate | X | 1 (0.454) |
| Lead chloride | A | 10 (4.54) |
| Lead fluoborate | A | 10 (4.54) |
| Lead fluoride | A | 10 (4.54) |
| Lead iodide | A | 10 (4.54) |
| Lead nitrate | A | 10 (4.54) |
| Lead stearate | A | 10 (4.54) |
| Lead sulfate | A | 10 (4.54) |
| Lead sulfide | A | 10 (4.54) |
| Lead thiocyanate | A | 10 (4.54) |
| Lindane | X | 1 (0.454) |
| Lithium chromate | A | 10 (4.54) |
| Malathion | B | 100 (45.4) |
| Maleic acid | D | 5,000 (2,270) |
| Maleic anhydride | D | 5,000 (2,270) |
| Mercaptodimethur | A | 10 (4.54) |
| Mercuric cyanide | X | 1 (0.454) |
| Mercuric nitrate | A | 10 (4.54) |
| Mercuric sulfate | A | 10 (4.54) |
| Mercuric thiocyanate | A | 10 (4.54) |
| Mercurous nitrate | A | 10 (4.54) |
| Methoxychlor | X | 1 (0.454) |
| Methyl mercaptan | B | 100 (45.4) |
| Methyl methacrylate | C | 1,000 (454) |
| Methyl parathion | B | 100 (45.4) |
| Mevinphos | A | 10 (4.54) |
| Mexacarbate | C | 1,000 (454) |
| Monoethylamine | B | 100 (45.4) |
| Monomethylamine | B | 100 (45.4) |
| Naled | A | 10 (4.54) |
| Naphthalene | B | 100 (45.4) |
| Naphthenic acid | B | 100 (45.4) |
| Nickel ammonium sulfate | B | 100 (45.4) |
| Nickel chloride | B | 100 (45.4) |
| Nickel hydroxide | A | 10 (4.54) |
| Nickel nitrate | B | 100 (45.4) |
| Nickel sulfate | B | 100 (45.4) |
| Nitric acid | C | 1,000 (454) |
| Nitrobenzene | C | 1,000 (454) |
| Nitrogen dioxide | A | 10 (4.54) |
| Nitrophenol (mixed) | B | 100 (45.4) |
| Nitrotoluene | C | 1,000 (454) |
| Paraformaldehyde | C | 1,000 (454) |
| Parathion | A | 10 (4.54) |
| Pentachlorophenol | A | 10 (4.54) |
| Phenol | C | 1,000 (454) |
| Phosgene | A | 10 (4.54) |
| Phosphoric acid | D | 5,000 (2,270) |
| Phosphorus | X | 1 (0.454) |
| Phosphorus oxychloride | C | 1,000 (454) |
| Phosphorus pentasulfide | B | 100 (45.4) |
| Phosphorus trichloride | C | 1,000 (454) |
| Polychlorinated biphenyls | X | 1 (0.454) |
| Potassium arsenate | X | 1 (0.454) |
| Potassium arsenite | X | 1 (0.454) |
| Potassium bichromate | A | 10 (4.54) |
| Potassium chromate | A | 10 (4.54) |
| Potassium cyanide | A | 10 (4.54) |
| Potassium hydroxide | C | 1,000 (454) |
| Potassium permanganate | B | 100 (45.4) |
| Propargite | A | 10 (4.54) |
| Propionic acid | D | 5,000 (2,270) |
| Propionic anhydride | D | 5,000 (2,270) |
| Propylene oxide | B | 100 (45.4) |
| Pyrethrins | X | 1 (0.454) |
| Quinoline | D | 5,000 (2,270) |
| Resorcinol | D | 5,000 (2,270) |
| Selenium oxide | A | 10 (4.54) |
| Silver nitrate | X | 1 (0.454) |
| Sodium | A | 10 (4.54) |
| Sodium arsenate | X | 1 (0.454) |
| Sodium arsenite | X | 1 (0.454) |
| Sodium bichromate | A | 10 (4.54) |
| Sodium bifluoride | B | 100 (45.4) |
| Sodium bisulfite | D | 5,000 (2,270) |
| Sodium chromate | A | 10 (4.54) |
| Sodium cyanide | A | 10 (4.54) |
| Sodium dodecylbenzenesulfonate | C | 1,000 (454) |
| Sodium fluoride | C | 1,000 (454) |
| Sodium hydrosulfide | D | 5,000 (2,270) |
| Sodium hydroxide | C | 1,000 (454) |
| Sodium hypochlorite | B | 100 (45.4) |
| Sodium methylate | C | 1,000 (454) |
| Sodium nitrite | B | 100 (45.4) |
| Sodium phosphate, dibasic | D | 5,000 (2,270) |
| Sodium phosphate, tribasic | D | 5,000 (2,270) |
| Sodium selenite | B | 100 (45.4) |
| Strontium chromate | A | 10 (4.54) |
| Strychnine | A | 10 (4.54) |
| Styrene | C | 1,000 (454) |
| Sulfuric acid | C | 1,000 (454) |
| Sulfur monochloride | C | 1,000 (454) |
| 2,4,5-T acid | C | 1,000 (454) |
| 2,4,5-T amines | D | 5,000 (2,270) |
| 2,4,5-T esters | C | 1,000 (454) |
| 2,4,5-T salts | C | 1,000 (454) |
| TDE | X | 1 (0.454) |
| 2,4,5-TP acid | B | 100 (45.4) |
| 2,4,5-TP acid esters | B | 100 (45.4) |
| Tetraethyl lead | A | 10 (4.54) |
| Tetraethyl pyrophosphate | A | 10 (4.54) |
| Thallium sulfate | B | 100 (45.4) |
| Toluene | C | 1,000 (454) |
| Toxaphene | X | 1 (0.454) |
| Trichlorfon | B | 100 (45.4) |
| Trichloroethylene | B | 100 (45.4) |
| Trichlorophenol | A | 10 (4.54) |
| Triethanolamine dodecylbenzenesulfonate | C | 1,000 (454) |
| Triethylamine | D | 5,000 (2,270) |
| Trimethylamine | B | 100 (45.4) |
| Uranyl acetate | B | 100 (45.4) |
| Uranyl nitrate | B | 100 (45.4) |
| Vanadium pentoxide | C | 1,000 (454) |
| Vanadyl sulfate | C | 1,000 (454) |
| Vinyl acetate | D | 5,000 (2,270) |
| Vinylidene chloride | B | 100 (45.4) |
| Xylene (mixed) | B | 100 (45.4) |
| Xylenol | C | 1,000 (454) |
| Zinc acetate | C | 1,000 (454) |
| Zinc ammonium chloride | C | 1,000 (454) |
| Zinc borate | C | 1,000 (454) |
| Zinc bromide | C | 1,000 (454) |
| Zinc carbonate | C | 1,000 (454) |
| Zinc chloride | C | 1,000 (454) |
| Zinc cyanide | A | 10 (4.54) |
| Zinc fluoride | C | 1,000 (454) |
| Zinc formate | C | 1,000 (454) |
| Zinc hydrosulfite | C | 1,000 (454) |
| Zinc nitrate | C | 1,000 (454) |
| Zinc phenolsulfonate | D | 5,000 (2,270) |
| Zinc phosphide | B | 100 (45.4) |
| Zinc silicofluoride | D | 5,000 (2,270) |
| Zinc sulfate | C | 1,000 (454) |
| Zirconium nitrate | D | 5,000 (2,270) |
| Zirconium potassium fluoride | C | 1,000 (454) |
| Zirconium sulfate | D | 5,000 (2,270) |
| Zirconium tetrachloride | D | 5,000 (2,270) |
Subpart B – Applicability
§ 117.11 General applicability.
This regulation sets forth a determination of the reportable quantity for each substance designated as hazardous in 40 CFR part 116. The regulation applies to quantities of designated substances equal to or greater than the reportable quantities, when discharged into or upon the navigable waters of the United States, adjoining shorelines, into or upon the contiguous zone, or beyond the contiguous zone as provided in section 311(b)(3) of the Act, except to the extent that the owner or operator can show such that discharges are made:
(a) In compliance with a permit issued under the Marine Protection, Research and Sanctuaries Act of 1972 (33 U.S.C. 1401 et seq.);
(b) In compliance with approved water treatment plant operations as specified by local or State regulations pertaining to safe drinking water;
(c) Pursuant to the label directions for application of a pesticide product registered under section 3 or section 24 of the Federal Insecticide, Fungicide, and Rodenticide Act (FIFRA), as amended (7 U.S.C. 136 et seq.), or pursuant to the terms and conditions of an experimental use permit issued under section 5 of FIFRA, or pursuant to an exemption granted under section 18 of FIFRA;
(d) In compliance with the regulations issued under section 3004 or with permit conditions issued pursuant to section 3005 of the Resource Conservation and Recovery Act (90 Stat. 2795; 42 U.S.C. 6901);
(e) In compliance with instructions of the On-Scene Coordinator pursuant to 40 CFR part 1510 (the National Oil and Hazardous Substances Pollution Plan) or 33 CFR 153.10(e) (Pollution by Oil and Hazardous Substances) or in accordance with applicable removal regulations as required by section 311(j)(1)(A);
(f) In compliance with a permit issued under § 165.7 of Title 14 of the State of California Administrative Code;
(g) From a properly functioning inert gas system when used to provide inert gas to the cargo tanks of a vessel;
(h) From a permitted source and are excluded by § 117.12 of this regulation;
(i) To a POTW and are specifically excluded or reserved in § 117.13; or
(j) In compliance with a permit issued under section 404(a) of the Clean Water Act or when the discharges are exempt from such requirements by section 404(f) or 404(r) of the Act (33 U.S.C. 1344(a), (f), (r)).
§ 117.12 Applicability to discharges from facilities with NPDES permits.
(a) This regulation does not apply to:
(1) Discharges in compliance with a permit under section 402 of this Act;
(2) Discharges resulting from circumstances identified, reviewed and made a part of the public record with respect to a permit issued or modified under section 402 of this Act, and subject to a condition in such permit;
(3) Continuous or anticipated intermittent discharges from a point source, identified in a permit or permit application under section 402 of this Act, which are caused by events occurring within the scope of the relevant operating or treatment systems; or
(b) A discharge is “in compliance with a permit issued under section 402 of this Act” if the permit contains an effluent limitation specifically applicable to the substance discharged or an effluent limitation applicable to another waste parameter which has been specifically identified in the permit as intended to limit such substance, and the discharge is in compliance with the effluent limitation.
(c) A discharge results “from circumstances identified, reviewed and made a part of the public record with respect to a permit issued or modified under section 402 of the Act, and subject to a condition in such permit,” whether or not the discharge is in compliance with the permit, where:
(1) The permit application, the permit, or another portion of the public record contains documents that specifically identify:
(i) The substance and the amount of the substance; and
(ii) The origin and source of the substance; and
(iii) The treatment which is to be provided for the discharge either by:
(A) An on-site treatment system separate from any treatment system treating the permittee’s normal discharge; or
(B) A treatment system designed to treat the permittee’s normal discharge and which is additionally capable of treating the identified amount of the identified substance; or
(C) Any combination of the above; and
(2) The permit contains a requirement that the substance and amounts of the substance, as identified in § 117.12(c)(1)(i) and § 117.12(c)(1)(ii) be treated pursuant to § 117.12(c)(1)(iii) in the event of an on-site release; and
(3) The treatment to be provided is in place.
(d) A discharge is a “continuous or anticipated intermittent discharge from a point source, identified in a permit or permit application under section 402 of this Act, and caused by events occurring within the scope of the relevant operating or treatment systems,” whether or not the discharge is in compliance with the permit, if:
(1) The hazardous substance is discharged from a point source for which a valid permit exists or for which a permit application has been submitted; and
(2) The discharge of the hazardous substance results from:
(i) The contamination of noncontact cooling water or storm water, provided that such cooling water or storm water is not contaminated by an on-site spill of a hazardous substance; or
(ii) A continuous or anticipated intermittent discharge of process waste water, and the discharge originates within the manufacturing or treatment systems; or
(iii) An upset or failure of a treatment system or of a process producing a continuous or anticipated intermittent discharge where the upset or failure results from a control problem, an operator error, a system failure or malfunction, an equipment or system startup or shutdown, an equipment wash, or a production schedule change, provided that such upset or failure is not caused by an on-site spill of a hazardous substance.
§ 117.13 Applicability to discharges from publicly owned treatment works and their users.
(a) [Reserved]
(b) These regulations apply to all discharges of reportable quantities to a POTW, where the discharge originates from a mobile source, except where such source has contracted with, or otherwise received written permission from the owners or operators of the POTW to discharge that quantity, and the mobile source can show that prior to accepting the substance from an industrial discharger, the substance had been treated to comply with any effluent limitation under sections 301, 302 or 306 or pretreatment standard under section 307 applicable to that facility.
§ 117.14 Demonstration projects.
Notwithstanding any other provision of this part, the Administrator of the Environmental Protection Agency may, on a case-by-case basis, allow the discharge of designated hazardous substances in connection with research or demonstration projects relating to the prevention, control, or abatement of hazardous substance pollution. The Administrator will allow such a discharge only where he determines that the expected environmental benefit from such a discharge will outweigh the potential hazard associated with the discharge.
Subpart C – Notice of Discharge of a Reportable Quantity
§ 117.21 Notice.
Any person in charge of a vessel or an onshore or an offshore facility shall, as soon as he has knowledge of any discharge of a designated hazardous substance from such vessel or facility in quantities equal to or exceeding in any 24-hour period the reportable quantity determined by this part, immediately notify the appropriate agency of the United States Government of such discharge. Notice shall be given in accordance with such procedures as the Secretary of Transportation has set forth in 33 CFR 153.203. This provision applies to all discharges not specifically excluded or reserved by another section of these regulations.
§ 117.23 Liabilities for removal.
In any case where a substance designated as hazardous in 40 CFR part 116 is discharged from any vessel or onshore or offshore facility in a quantity equal to or exceeding the reportable quantity determined by this part, the owner, operator or person in charge will be liable, pursuant to section 311 (f) and (g) of the Act, to the United States Government for the actual costs incurred in the removal of such substance, subject only to the defenses and monetary limitations enumerated in section 311 (f) and (g) of the Act.
PART 120 – DEFINITION OF WATERS OF THE UNITED STATES
§ 120.1 Purpose and scope.
This part contains the definition of “waters of the United States” for purposes of the Clean Water Act, 33 U.S.C. 1251 et seq. and its implementing regulations. EPA regulations implementing the Clean Water Act use the term “navigable waters,” which is defined at section 502(7) of the Clean Water Act as “the waters of the United States, including the territorial seas,” or the term “waters of the United States.” In light of the statutory definition, the definition in this section establishes the scope of the terms “waters of the United States” and “navigable waters” in EPA’s regulations.
§ 120.2 Definitions.
For the purpose of this regulation these terms are defined as follows:
(a) Waters of the United States means:
(1) Waters which are:
(i) Currently used, or were used in the past, or may be susceptible to use in interstate or foreign commerce, including all waters which are subject to the ebb and flow of the tide;
(ii) The territorial seas; or
(iii) Interstate waters, including interstate wetlands;
(2) Impoundments of waters otherwise defined as waters of the United States under this definition, other than impoundments of waters identified under paragraph (a)(5) of this section;
(3) Tributaries of waters identified in paragraph (a)(1) or (2) of this section:
(i) That are relatively permanent, standing or continuously flowing bodies of water; or
(ii) That either alone or in combination with similarly situated waters in the region, significantly affect the chemical, physical, or biological integrity of waters identified in paragraph (a)(1) of this section;
(4) Wetlands adjacent to the following waters:
(i) Waters identified in paragraph (a)(1) of this section; or
(ii) Relatively permanent, standing or continuously flowing bodies of water identified in paragraph (a)(2) or (a)(3)(i) of this section and with a continuous surface connection to those waters; or
(iii) Waters identified in paragraph (a)(2) or (3) of this section when the wetlands either alone or in combination with similarly situated waters in the region, significantly affect the chemical, physical, or biological integrity of waters identified in paragraph (a)(1) of this section;
(5) Intrastate lakes and ponds, streams, or wetlands not identified in paragraphs (a)(1) through (4) of this section:
(i) That are relatively permanent, standing or continuously flowing bodies of water with a continuous surface connection to the waters identified in paragraph (a)(1) or (a)(3)(i) of this section; or
(ii) That either alone or in combination with similarly situated waters in the region, significantly affect the chemical, physical, or biological integrity of waters identified in paragraph (a)(1) of this section.
(b) The following are not “waters of the United States” even where they otherwise meet the terms of paragraphs (a)(2) through (5) of this section:
(1) Waste treatment systems, including treatment ponds or lagoons, designed to meet the requirements of the Clean Water Act;
(2) Prior converted cropland designated by the Secretary of Agriculture. The exclusion would cease upon a change of use, which means that the area is no longer available for the production of agricultural commodities. Notwithstanding the determination of an area’s status as prior converted cropland by any other Federal agency, for the purposes of the Clean Water Act, the final authority regarding Clean Water Act jurisdiction remains with EPA;
(3) Ditches (including roadside ditches) excavated wholly in and draining only dry land and that do not carry a relatively permanent flow of water;
(4) Artificially irrigated areas that would revert to dry land if the irrigation ceased;
(5) Artificial lakes or ponds created by excavating or diking dry land to collect and retain water and which are used exclusively for such purposes as stock watering, irrigation, settling basins, or rice growing;
(6) Artificial reflecting or swimming pools or other small ornamental bodies of water created by excavating or diking dry land to retain water for primarily aesthetic reasons;
(7) Waterfilled depressions created in dry land incidental to construction activity and pits excavated in dry land for the purpose of obtaining fill, sand, or gravel unless and until the construction or excavation operation is abandoned and the resulting body of water meets the definition of waters of the United States; and
(8) Swales and erosional features (e.g., gullies, small washes) characterized by low volume, infrequent, or short duration flow.
(c) In this section, the following definitions apply:
(1) Wetlands means those areas that are inundated or saturated by surface or ground water at a frequency and duration sufficient to support, and that under normal circumstances do support, a prevalence of vegetation typically adapted for life in saturated soil conditions. Wetlands generally include swamps, marshes, bogs, and similar areas.
(2) Adjacent means bordering, contiguous, or neighboring. Wetlands separated from other waters of the United States by man-made dikes or barriers, natural river berms, beach dunes, and the like are “adjacent wetlands.”
(3) High tide line means the line of intersection of the land with the water’s surface at the maximum height reached by a rising tide. The high tide line may be determined, in the absence of actual data, by a line of oil or scum along shore objects, a more or less continuous deposit of fine shell or debris on the foreshore or berm, other physical markings or characteristics, vegetation lines, tidal gages, or other suitable means that delineate the general height reached by a rising tide. The line encompasses spring high tides and other high tides that occur with periodic frequency but does not include storm surges in which there is a departure from the normal or predicted reach of the tide due to the piling up of water against a coast by strong winds such as those accompanying a hurricane or other intense storm.
(4) Ordinary high water mark means that line on the shore established by the fluctuations of water and indicated by physical characteristics such as clear, natural line impressed on the bank, shelving, changes in the character of soil, destruction of terrestrial vegetation, the presence of litter and debris, or other appropriate means that consider the characteristics of the surrounding areas.
(5) Tidal waters means those waters that rise and fall in a predictable and measurable rhythm or cycle due to the gravitational pulls of the moon and sun. Tidal waters end where the rise and fall of the water surface can no longer be practically measured in a predictable rhythm due to masking by hydrologic, wind, or other effects.
(6) Significantly affect means a material influence on the chemical, physical, or biological integrity of waters identified in paragraph (a)(1) of this section. To determine whether waters, either alone or in combination with similarly situated waters in the region, have a material influence on the chemical, physical, or biological integrity of waters identified in paragraph (a)(1) of this section, the functions identified in paragraph (c)(6)(i) of this section will be assessed and the factors identified in paragraph (c)(6)(ii) of this section will be considered:
(i) Functions to be assessed:
(A) Contribution of flow;
(B) Trapping, transformation, filtering, and transport of materials (including nutrients, sediment, and other pollutants);
(C) Retention and attenuation of floodwaters and runoff;
(D) Modulation of temperature in waters identified in paragraph (a)(1) of this section; or
(E) Provision of habitat and food resources for aquatic species located in waters identified in paragraph (a)(1) of this section;
(ii) Factors to be considered:
(A) The distance from a water identified in paragraph (a)(1) of this section;
(B) Hydrologic factors, such as the frequency, duration, magnitude, timing, and rate of hydrologic connections, including shallow subsurface flow;
(C) The size, density, or number of waters that have been determined to be similarly situated;
(D) Landscape position and geomorphology; and
(E) Climatological variables such as temperature, rainfall, and snowpack.
PART 121 – STATE CERTIFICATION OF ACTIVITIES REQUIRING A FEDERAL LICENSE OR PERMIT
Subpart A – General
§ 121.1 Definitions.
(a) Administrator means the Administrator of the Environmental Protection Agency or an authorized representative.
(b) Certification means a water quality certification issued in accordance with Clean Water Act section 401 and this part.
(c) Certification request means a written, signed, and dated communication that satisfies the requirements of § 121.5(b) or (c).
(d) Certified project means a proposed project that has received a certification or for which the certification requirement has been waived.
(e) Certifying authority means the agency responsible for certifying compliance with applicable water quality requirements in accordance with Clean Water Act section 401.
(f) Discharge for purposes of this part means a discharge from a point source into a water of the United States.
(g) Federal agency means any agency of the Federal Government to which application is made for a license or permit that is subject to Clean Water Act section 401.
(h) License or permit means any license or permit granted by an agency of the Federal Government to conduct any activity which may result in a discharge.
(i) Neighboring jurisdiction means any other state or authorized tribe whose water quality the Administrator determines may be affected by a discharge for which a certification is granted pursuant to Clean Water Act section 401 and this part.
(j) Project proponent means the applicant for a license or permit or the entity seeking certification.
(k) Proposed project means the activity or facility for which the project proponent has applied for a license or permit.
(l) Reasonable period of time means the time period during which a certifying authority may act on a certification request, established in accordance with § 121.6 of this part.
(m) Receipt means the date that a certification request is documented as received by a certifying authority in accordance with applicable submission procedures.
(n) Water quality requirements means applicable provisions of §§ 301, 302, 303, 306, and 307 of the Clean Water Act, and state or tribal regulatory requirements for point source discharges into waters of the United States.
Subpart B – Certification Procedures
§ 121.2 When certification is required.
Certification is required for any license or permit that authorizes an activity that may result in a discharge.
§ 121.3 Scope of certification.
The scope of a Clean Water Act section 401 certification is limited to assuring that a discharge from a Federally licensed or permitted activity will comply with water quality requirements.
§ 121.4 Pre-filing meeting request.
(a) At least 30 days prior to submitting a certification request, the project proponent shall request a pre-filing meeting with the certifying authority.
(b) The certifying authority is not obligated to grant or respond to the pre-filing meeting request.
(c) If the certifying authority grants the pre-filing meeting request, the project proponent and the certifying authority are encouraged to discuss the nature of the proposed project and potential water quality effects. The project proponent is encouraged to provide a list of other required state, interstate, tribal, territorial, and federal authorizations and to describe the anticipated timeline for construction and operation.
(d) After receiving the pre-filing meeting request, the certifying authority is encouraged to contact the Federal agency and to identify points of contact to facilitate information sharing between the certifying authority and Federal agency throughout the certification process.
§ 121.5 Certification request.
(a) A certification request shall be submitted to the certifying authority and to the Federal agency concurrently.
(b) A certification request for an individual license or permit shall:
(1) Identify the project proponent(s) and a point of contact;
(2) Identify the proposed project;
(3) Identify the applicable federal license or permit;
(4) Identify the location and nature of any potential discharge that may result from the proposed project and the location of receiving waters;
(5) Include a description of any methods and means proposed to monitor the discharge and the equipment or measures planned to treat, control, or manage the discharge;
(6) Include a list of all other federal, interstate, tribal, state, territorial, or local agency authorizations required for the proposed project, including all approvals or denials already received;
(7) Include documentation that a pre-filing meeting request was submitted to the certifying authority at least 30 days prior to submitting the certification request;
(8) Contain the following statement: `The project proponent hereby certifies that all information contained herein is true, accurate, and complete to the best of my knowledge and belief’; and
(9) Contain the following statement: `The project proponent hereby requests that the certifying authority review and take action on this CWA 401 certification request within the applicable reasonable period of time.‘
(c) A certification request for issuance of a general license or permit shall:
(1) Identify the project proponent(s) and a point of contact;
(2) Identify the proposed categories of activities to be authorized by the general license or permit for which certification is requested;
(3) Include the draft or proposed general license or permit;
(4) Estimate the number of discharges expected to be authorized by the proposed general license or permit each year;
(5) Include documentation that a pre-filing meeting request was submitted to the certifying authority at least 30 days prior to submitting the certification request;
(6) Contain the following statement: `The project proponent hereby certifies that all information contained herein is true, accurate, and complete to the best of my knowledge and belief ‘; and
(7) Contain the following statement: `The project proponent hereby requests that the certifying authority review and take action on this CWA 401 certification request within the applicable reasonable period of time.‘
§ 121.6 Establishing the reasonable period of time.
(a) The Federal agency shall establish the reasonable period of time either categorically or on a case-by-case basis. In either event, the reasonable period of time shall not exceed one year from receipt.
(b) Within 15 days of receiving notice of the certification request from the project proponent, the Federal agency shall provide, in writing, the following information to the certifying authority:
(1) The date of receipt;
(2) The applicable reasonable period of time to act on the certification request; and
(3) The date upon which waiver will occur if the certifying authority fails or refuses to act on the certification request.
(c) In establishing the reasonable period of time, the Federal agency shall consider:
(1) The complexity of the proposed project;
(2) The nature of any potential discharge; and
(3) The potential need for additional study or evaluation of water quality effects from the discharge.
(d) The Federal agency may extend the reasonable period of time at the request of a certifying authority or a project proponent, but in no case shall the reasonable period of time exceed one year from receipt.
(1) Any request by a certifying authority or project proponent to the Federal agency to extend the reasonable period of time shall be in writing.
(2) If the Federal agency agrees to extend the reasonable period of time, the Federal agency shall notify the certifying authority and project proponent in writing.
(e) The certifying authority is not authorized to request the project proponent to withdraw a certification request and is not authorized to take any action to extend the reasonable period of time other than specified in § 121.6(d).
§ 121.7 Action on a certification request.
(a) Any action by the certifying authority to grant, grant with conditions, or deny a certification request must be within the scope of certification, must be completed within the reasonable period of time, and must otherwise be in accordance with section 401 of the Clean Water Act. Alternatively, a certifying authority may expressly waive certification.
(b) If the certifying authority determines that a discharge from a proposed project will comply with water quality requirements, it may issue or waive certification. If the certifying authority cannot certify that the discharge from a proposed project will comply with water quality requirements, it may deny or waive certification.
(c) Any grant of certification shall be in writing and shall include a statement that the discharge from the proposed project will comply with water quality requirements.
(d) Any grant of certification with conditions shall be in writing and shall for each condition include, at a minimum:
(1) For certification conditions on an individual license or permit,
(i) A statement explaining why the condition is necessary to assure that the discharge from the proposed project will comply with water quality requirements; and
(ii) A citation to federal, state, or tribal law that authorizes the condition.
(2) For certification conditions on issuance of a general license or permit,
(i) A statement explaining why the condition is necessary to assure that any discharge authorized under the general license or permit will comply with water quality requirements; and
(ii) A citation to federal, state, or tribal law that authorizes the condition.
(e) Any denial of certification shall be in writing and shall include:
(1) For denial of certification for an individual license or permit,
(i) The specific water quality requirements with which the discharge will not comply;
(ii) A statement explaining why the discharge will not comply with the identified water quality requirements; and
(iii) If the denial is due to insufficient information, the denial must describe the specific water quality data or information, if any, that would be needed to assure that the discharge from the proposed project will comply with water quality requirements.
(2) For denial of certification for issuance of a general license or permit,
(i) The specific water quality requirements with which discharges that could be authorized by the general license or permit will not comply;
(ii) A statement explaining why discharges that could be authorized by the general license or permit will not comply with the identified water quality requirements; and
(iii) If the denial is due to insufficient information, the denial must describe the types of water quality data or information, if any, that would be needed to assure that the range of discharges from potential projects will comply with water quality requirements.
(f) If the certifying authority determines that no water quality requirements are applicable to the waters receiving the discharge from the proposed project, the certifying authority shall grant certification.
§ 121.8 Effect of denial of certification.
(a) A certification denial shall not preclude a project proponent from submitting a new certification request, in accordance with the substantive and procedural requirements of this part.
(b) Where a Federal agency determines that a certifying authority’s denial satisfies the requirements of § 121.7(e), the Federal agency must provide written notice of such determination to the certifying authority and project proponent, and the license or permit shall not be granted.
§ 121.9 Waiver.
(a) The certification requirement for a license or permit shall be waived upon:
(1) Written notification from the certifying authority to the project proponent and the Federal agency that the certifying authority expressly waives its authority to act on a certification request; or
(2) The certifying authority’s failure or refusal to act on a certification request, including:
(i) Failure or refusal to act on a certification request within the reasonable period of time;
(ii) Failure or refusal to satisfy the requirements of § 121.7(c);
(iii) Failure or refusal to satisfy the requirements of § 121.7(e); or
(iv) Failure or refusal to comply with other procedural requirements of section 401.
(b) A condition for a license or permit shall be waived upon the certifying authority’s failure or refusal to satisfy the requirements of § 121.7(d).
(c) If the certifying authority fails or refuses to act, as provided in this section, the Federal agency shall provide written notice to the Administrator, certifying authority, and project proponent that waiver of the certification requirement or condition has occurred. This notice must be in writing and include the notice that the Federal agency provided to the certifying authority pursuant to § 121.6(b).
(d) A written notice of waiver from the Federal agency shall satisfy the project proponent’s requirement to obtain certification.
(e) Upon issuance of a written notice of waiver, the Federal agency may issue the license or permit.
§ 121.10 Incorporation of certification conditions into the license or permit.
(a) All certification conditions that satisfy the requirements of § 121.7(d) shall be incorporated into the license or permit.
(b) The license or permit must clearly identify any certification conditions.
§ 121.11 Enforcement of and compliance with certification conditions.
(a) The certifying authority, prior to the initial operation of a certified project, shall be afforded the opportunity to inspect the facility or activity for the purpose of determining whether the discharge from the certified project will violate the certification.
(b) If the certifying authority, after an inspection pursuant to subsection (a), determines that the discharge from the certified project will violate the certification, the certifying authority shall notify the project proponent and the Federal agency in writing, and recommend remedial measures necessary to bring the certified project into compliance with the certification.
(c) The Federal agency shall be responsible for enforcing certification conditions that are incorporated into a federal license or permit.
Subpart C – Other Jurisdictions
§ 121.12 Determination of effects on neighboring jurisdictions.
(a) A Federal agency shall within 5 days notify the Administrator when it receives a license or permit application and the related certification.
(b) Within 30 days after the Administrator receives notice in accordance with § 121.12(a), the Administrator at his or her discretion may determine that the discharge from the certified project may affect water quality in a neighboring jurisdiction. In making this determination and in accordance with applicable law, the Administrator may request copies of the certification and the federal license or permit application.
(c) If the Administrator determines that the discharge from the certified project may affect water quality in a neighboring jurisdiction, the Administrator, within 30 days after receiving notice in accordance with § 121.12(a), shall notify that neighboring jurisdiction, the certifying authority, the Federal agency, and the project proponent. The federal license or permit may not be issued pending the conclusion of the processes in this paragraph.
(1) Notification from the Administrator shall: Be in writing, be dated, and identify the materials provided by the Federal agency. The notification shall inform the neighboring jurisdiction that it has 60 days to notify the Administrator and the Federal agency, in writing, whether it has determined that the discharge will violate any of its water quality requirements, to object to the issuance of the federal license or permit, and to request a public hearing from the Federal agency.
(2) Notification of objection and request for a hearing from the neighboring jurisdiction shall: Be in writing; identify the receiving waters it determined will be affected by the discharge; and identify the specific water quality requirements it determines will be violated by the certified project.
(3) If the neighboring jurisdiction requests a hearing in accordance with § 121.12(c)(2), the Federal agency shall hold a public hearing on the neighboring jurisdiction’s objection to the license or permit.
(i) The Federal agency shall provide the hearing notice to the Administrator at least 30 days before the hearing takes place.
(ii) At the hearing, the Administrator shall submit to the Federal agency his or her evaluation and recommendation(s) concerning the objection.
(iii) The Federal agency shall: Consider recommendations from the neighboring jurisdiction and the Administrator, and any additional evidence presented to the Federal agency at the hearing; and determine whether additional certification conditions are necessary to assure that the discharge from the certified project will comply with the neighboring jurisdiction’s water quality requirements.
(iv) If additional certification conditions cannot assure that the discharge from the certified project will comply with the neighboring jurisdiction’s water quality requirements, the Federal agency shall not issue the license or permit.
Subpart D – Certification by the Administrator
§ 121.13 When the Administrator certifies.
(a) Certification by the Administrator that the discharge from a proposed project will comply with water quality requirements is required where no state, tribe, or interstate agency has authority to give such a certification.
(b) In taking action pursuant to this paragraph, the Administrator shall comply with the requirements of Clean Water Act section 401 and 40 CFR part 121.
§ 121.14 Request for additional information.
(a) If necessary, the Administrator may request additional information from the project proponent, provided that the initial request is made within 30 days of receipt.
(b) The Administrator shall request only additional information that is within the scope of certification and is directly related to the discharge from the proposed project and its potential effect on receiving waters.
(c) The Administrator shall request only information that can be collected or generated within the reasonable period of time.
(d) In any request for additional information, the Administrator shall include a deadline for the project proponent to respond.
(1) The project proponent shall comply with the deadline established by the Administrator.
(2) The deadline must allow sufficient time for the Administrator to review the additional information and to act on the certification request within the reasonable period of time.
(e) Failure of a project proponent to timely provide the Administrator with additional information does not extend the reasonable period of time or prevent the Administrator from taking action on a certification request.
§ 121.15 Notice and hearing.
(a) Within 20 days of receipt, the Administrator shall provide appropriate public notice of receipt, including to parties known to be interested in the proposed project or in the receiving waters into which the discharge may occur.
(b) If the Administrator in his or her discretion determines that a public hearing is appropriate or necessary, the EPA shall: Schedule such hearing at an appropriate time and place; and, to the extent practicable, give all interested and affected parties the opportunity to present evidence or testimony in person or by other means at the hearing.
Subpart E – Consultations
§ 121.16 Review and advice.
The Administrator may, and upon request shall, provide Federal agencies, certifying authorities, and project proponents with relevant information and assistance regarding the meaning of, content of, application of, and methods to comply with water quality requirements.
PART 122 – EPA ADMINISTERED PERMIT PROGRAMS: THE NATIONAL POLLUTANT DISCHARGE ELIMINATION SYSTEM
Subpart A – Definitions and General Program Requirements
§ 122.1 Purpose and scope.
(a) Coverage. (1) The regulatory provisions contained in this part and parts 123, and 124 of this chapter implement the National Pollutant Discharge Elimination System (NPDES) Program under sections 318, 402, and 405 of the Clean Water Act (CWA) (Public Law 92-500, as amended, 33 U.S.C. 1251 et seq.)
(2) These provisions cover basic EPA permitting requirements (this part 122), what a State must do to obtain approval to operate its program in lieu of a Federal program and minimum requirements for administering the approved State program (part 123 of this chapter), and procedures for EPA processing of permit applications and appeals (part 124 of this chapter).
(3) These provisions also establish the requirements for public participation in EPA and State permit issuance and enforcement and related variance proceedings, and in the approval of State NPDES programs. These provisions carry out the purposes of the public participation requirements of part 25 of this chapter, and supersede the requirements of that part as they apply to actions covered under this part and parts 123, and 124 of this chapter.
(4) Regulatory provisions in Parts 125, 129, 133, 136 of this chapter and 40 CFR subchapter N and subchapter O of this chapter also implement the NPDES permit program.
(5) Certain requirements set forth in parts 122 and 124 of this chapter are made applicable to approved State programs by reference in part 123 of this chapter. These references are set forth in § 123.25 of this chapter. If a section or paragraph of part 122 or 124 of this chapter is applicable to States, through reference in § 123.25 of this chapter, that fact is signaled by the following words at the end of the section or paragraph heading: (Applicable to State programs, see § 123.25 of this chapter). If these words are absent, the section (or paragraph) applies only to EPA administered permits. Nothing in this part and parts 123, or 124 of this chapter precludes more stringent State regulation of any activity covered by the regulations in 40 CFR parts 122, 123, and 124, whether or not under an approved State program.
(b) Scope of the NPDES permit requirement. (1) The NPDES program requires permits for the discharge of “pollutants” from any “point source” into “waters of the United States.” The terms “pollutant”, “point source” and “waters of the United States” are defined at § 122.2.
(2) The permit program established under this part also applies to owners or operators of any treatment works treating domestic sewage, whether or not the treatment works is otherwise required to obtain an NPDES permit, unless all requirements implementing section 405(d) of the CWA applicable to the treatment works treating domestic sewage are included in a permit issued under the appropriate provisions of subtitle C of the Solid Waste Disposal Act, Part C of the Safe Drinking Water Act, the Marine Protection, Research, and Sanctuaries Act of 1972, or the Clean Air Act, or under State permit programs approved by the Administrator as adequate to assure compliance with section 405 of the CWA.
(3) The Regional Administrator may designate any person subject to the standards for sewage sludge use and disposal as a “treatment works treating domestic sewage” as defined in § 122.2, where the Regional Administrator finds that a permit is necessary to protect public health and the environment from the adverse effects of sewage sludge or to ensure compliance with the technical standards for sludge use and disposal developed under CWA section 405(d). Any person designated as a “treatment works treating domestic sewage” shall submit an application for a permit under § 122.21 within 180 days of being notified by the Regional Administrator that a permit is required. The Regional Administrator’s decision to designate a person as a “treatment works treating domestic sewage” under this paragraph shall be stated in the fact sheet or statement of basis for the permit.
Information concerning the NPDES program and its regulations can be obtained by contacting the Water Permits Division (4203), Office of Wastewater Management, U.S. EPA, 1200 Pennsylvania Avenue NW, Washington, DC 20460 and by visiting the homepage at http://www.epa.gov/npdes/.
§ 122.2 Definitions.
The following definitions apply to parts 122, 123, and 124. Terms not defined in this section have the meaning given by CWA. When a defined term appears in a definition, the defined term is sometimes placed in quotation marks as an aid to readers.
Administrator means the Administrator of the United States Environmental Protection Agency, or an authorized representative.
Animal feeding operation is defined at § 122.23.
Applicable standards and limitations means all State, interstate, and federal standards and limitations to which a “discharge,” a “sewage sludge use or disposal practice,” or a related activity is subject under the CWA, including “effluent limitations,” water quality standards, standards of performance, toxic effluent standards or prohibitions, “best management practices,” pretreatment standards, and “standards for sewage sludge use or disposal” under sections 301, 302, 303, 304, 306, 307, 308, 403 and 405 of CWA.
Application means the EPA standard national forms for applying for a permit, including any additions, revisions or modifications to the forms; or forms approved by EPA for use in “approved States,” including any approved modifications or revisions.
Approved program or approved State means a State or interstate program which has been approved or authorized by EPA under part 123.
Aquaculture project is defined at § 122.25.
Average monthly discharge limitation means the highest allowable average of “daily discharges” over a calendar month, calculated as the sum of all “daily discharges” measured during a calendar month divided by the number of “daily discharges” measured during that month.
Average weekly discharge limitation means the highest allowable average of “daily discharges” over a calendar week, calculated as the sum of all “daily discharges” measured during a calendar week divided by the number of “daily discharges” measured during that week.
Best management practices (“BMPs”) means schedules of activities, prohibitions of practices, maintenance procedures, and other management practices to prevent or reduce the pollution of “waters of the United States.” BMPs also include treatment requirements, operating procedures, and practices to control plant site runoff, spillage or leaks, sludge or waste disposal, or drainage from raw material storage.
BMPs means “best management practices.”
Class I sludge management facility means any POTW identified under 40 CFR 403.8(a) as being required to have an approved pretreatment program (including such POTWs located in a State that has elected to assume local program responsibilities pursuant to 40 CFR 403.10(e)) and any other treatment works treating domestic sewage classified as a Class I sludge management facility by the Regional Administrator, or, in the case of approved State programs, the Regional Administrator in conjunction with the State Director, because of the potential for its sludge use or disposal practices to adversely affect public health and the environment.
Bypass is defined at § 122.41(m).
Combined sewer overflow (CSO) means a discharge from a combined sewer system (CSS) at a point prior to the Publicly Owned Treatment Works (POTW) Treatment Plant (defined at § 403.3(r) of this chapter).
Combined sewer system (CSS) means a wastewater collection system owned by a State or municipality (as defined by section 502(4) of the CWA) which conveys sanitary wastewaters (domestic, commercial and industrial wastewaters) and storm water through a single-pipe system to a Publicly Owned Treatment Works (POTW) Treatment Plant (as defined at § 403.3(r) of this chapter).
Concentrated animal feeding operation is defined at § 122.23.
Concentrated aquatic animal feeding operation is defined at § 122.24.
Contiguous zone means the entire zone established by the United States under Article 24 of the Convention on the Territorial Sea and the Contiguous Zone.
Continuous discharge means a “discharge” which occurs without interruption throughout the operating hours of the facility, except for infrequent shutdowns for maintenance, process changes, or other similar activities.
CWA means the Clean Water Act (formerly referred to as the Federal Water Pollution Control Act or Federal Water Pollution Control Act Amendments of 1972) Public Law 92-500, as amended by Public Law 95-217, Public Law 95-576, Public Law 96-483 and Public Law 97-117, 33 U.S.C. 1251 et seq.
CWA and regulations means the Clean Water Act (CWA) and applicable regulations promulgated thereunder. In the case of an approved State program, it includes State program requirements.
Daily discharge means the “discharge of a pollutant” measured during a calendar day or any 24-hour period that reasonably represents the calendar day for purposes of sampling. For pollutants with limitations expressed in units of mass, the “daily discharge” is calculated as the total mass of the pollutant discharged over the day. For pollutants with limitations expressed in other units of measurement, the “daily discharge” is calculated as the average measurement of the pollutant over the day.
Direct discharge means the “discharge of a pollutant.”
Director means the Regional Administrator or the State Director, as the context requires, or an authorized representative. When there is no “approved State program,” and there is an EPA administered program, “Director” means the Regional Administrator. When there is an approved State program, “Director” normally means the State Director. In some circumstances, however, EPA retains the authority to take certain actions even when there is an approved State program. (For example, when EPA has issued an NPDES permit prior to the approval of a State program, EPA may retain jurisdiction over that permit after program approval, see § 123.1.) In such cases, the term “Director” means the Regional Administrator and not the State Director.
Discharge when used without qualification means the “discharge of a pollutant.”
Discharge of a pollutant means:
(a) Any addition of any “pollutant” or combination of pollutants to “waters of the United States” from any “point source,” or
(b) Any addition of any pollutant or combination of pollutants to the waters of the “contiguous zone” or the ocean from any point source other than a vessel or other floating craft which is being used as a means of transportation.
Discharge Monitoring Report (“DMR”) means the EPA uniform national form, including any subsequent additions, revisions, or modifications for the reporting of self-monitoring results by permittees. DMRs must be used by “approved States” as well as by EPA. EPA will supply DMRs to any approved State upon request. The EPA national forms may be modified to substitute the State Agency name, address, logo, and other similar information, as appropriate, in place of EPA’s.
DMR means “Discharge Monitoring Report.”
Draft permit means a document prepared under § 124.6 indicating the Director’s tentative decision to issue or deny, modify, revoke and reissue, terminate, or reissue a “permit.” A notice of intent to terminate a permit, and a notice of intent to deny a permit, as discussed in § 124.5, are types of “draft permits.” A denial of a request for modification, revocation and reissuance, or termination, as discussed in § 124.5, is not a “draft permit.” A “proposed permit” is not a “draft permit.”
Effluent limitation means any restriction imposed by the Director on quantities, discharge rates, and concentrations of “pollutants” which are “discharged” from “point sources” into “waters of the United States,” the waters of the “contiguous zone,” or the ocean.
Effluent limitations guidelines means a regulation published by the Administrator under section 304(b) of CWA to adopt or revise “effluent limitations.”
Environmental Protection Agency (“EPA”) means the United States Environmental Protection Agency.
EPA means the United States “Environmental Protection Agency.”
Facility or activity means any NPDES “point source” or any other facility or activity (including land or appurtenances thereto) that is subject to regulation under the NPDES program.
Federal Indian reservation means all land within the limits of any Indian reservation under the jurisdiction of the United States Government, notwithstanding the issuance of any patent, and including rights-of-way running through the reservation.
General permit means an NPDES “permit” issued under § 122.28 authorizing a category of discharges under the CWA within a geographical area.
Great Lakes Basin means the waters defined as “Great Lakes” and “Great Lakes System” as those terms are defined in § 132.2 of this chapter.
Hazardous substance means any substance designated under 40 CFR part 116 pursuant to section 311 of CWA.
Indian country means:
(1) All land within the limits of any Indian reservation under the jurisdiction of the United States Government, notwithstanding the issuance of any patent, and, including rights-of-way running through the reservation;
(2) All dependent Indian communities with the borders of the United States whether within the originally or subsequently acquired territory thereof, and whether within or without the limits of a state; and
(3) All Indian allotments, the Indian titles to which have not been extinguished, including rights-of-way running through the same.
Indian Tribe means any Indian Tribe, band, group, or community recognized by the Secretary of the Interior and exercising governmental authority over a Federal Indian reservation.
Indirect discharger means a nondomestic discharger introducing “pollutants” to a “publicly owned treatment works.”
Individual control strategy is defined at 40 CFR 123.46(c).
Interstate agency means an agency of two or more States established by or under an agreement or compact approved by the Congress, or any other agency of two or more States having substantial powers or duties pertaining to the control of pollution as determined and approved by the Administrator under the CWA and regulations.
Major facility means any NPDES “facility or activity” classified as such by the Regional Administrator, or, in the case of “approved State programs,” the Regional Administrator in conjunction with the State Director.
Maximum daily discharge limitation means the highest allowable “daily discharge.”
Municipality means a city, town, borough, county, parish, district, association, or other public body created by or under State law and having jurisdiction over disposal of sewage, industrial wastes, or other wastes, or an Indian tribe or an authorized Indian tribal organization, or a designated and approved management agency under section 208 of CWA.
Municipal separate storm sewer system is defined at § 122.26 (b)(4) and (b)(7).
National Pollutant Discharge Elimination System (NPDES) means the national program for issuing, modifying, revoking and reissuing, terminating, monitoring and enforcing permits, and imposing and enforcing pretreatment requirements, under sections 307, 402, 318, and 405 of CWA. The term includes an “approved program.”
New discharger means any building, structure, facility, or installation:
(a) From which there is or may be a “discharge of pollutants;”
(b) That did not commence the “discharge of pollutants” at a particular “site” prior to August 13, 1979;
(c) Which is not a “new source;” and
(d) Which has never received a finally effective NPDES permit for discharges at that “site.”
New source means any building, structure, facility, or installation from which there is or may be a “discharge of pollutants,” the construction of which commenced:
(a) After promulgation of standards of performance under section 306 of CWA which are applicable to such source, or
(b) After proposal of standards of performance in accordance with section 306 of CWA which are applicable to such source, but only if the standards are promulgated in accordance with section 306 within 120 days of their proposal.
NPDES means “National Pollutant Discharge Elimination System.”
Owner or operator means the owner or operator of any “facility or activity” subject to regulation under the NPDES program.
Permit means an authorization, license, or equivalent control document issued by EPA or an “approved State” to implement the requirements of this part and parts 123 and 124. “Permit” includes an NPDES “general permit” (§ 122.28). Permit does not include any permit which has not yet been the subject of final agency action, such as a “draft permit” or a “proposed permit.”
Person means an individual, association, partnership, corporation, municipality, State or Federal agency, or an agent or employee thereof.
Pesticide discharges to waters of the United States from pesticide application means the discharges that result from the application of biological pesticides, and the application of chemical pesticides that leave a residue, from point sources to waters of the United States. In the context of this definition of pesticide discharges to waters of the United States from pesticide application, this does not include agricultural storm water discharges and return flows from irrigated agriculture, which are excluded by law (33 U.S.C. 1342(l); 33 U.S.C. 1362(14)).
Pesticide residue for the purpose of determining whether an NPDES permit is needed for discharges to waters of the United States from pesticide application, means that portion of a pesticide application that is discharged from a point source to waters of the United States and no longer provides pesticidal benefits. It also includes any degradates of the pesticide.
Point source means any discernible, confined, and discrete conveyance, including but not limited to, any pipe, ditch, channel, tunnel, conduit, well, discrete fissure, container, rolling stock, concentrated animal feeding operation, landfill leachate collection system, vessel or other floating craft from which pollutants are or may be discharged. This term does not include return flows from irrigated agriculture or agricultural storm water runoff. (See § 122.3).
Pollutant means dredged spoil, solid waste, incinerator residue, filter backwash, sewage, garbage, sewage sludge, munitions, chemical wastes, biological materials, radioactive materials (except those regulated under the Atomic Energy Act of 1954, as amended (42 U.S.C. 2011 et seq.)), heat, wrecked or discarded equipment, rock, sand, cellar dirt and industrial, municipal, and agricultural waste discharged into water. It does not mean:
(a) Sewage from vessels; or
(b) Water, gas, or other material which is injected into a well to facilitate production of oil or gas, or water derived in association with oil and gas production and disposed of in a well, if the well used either to facilitate production or for disposal purposes is approved by authority of the State in which the well is located, and if the State determines that the injection or disposal will not result in the degradation of ground or surface water resources.
Radioactive materials covered by the Atomic Energy Act are those encompassed in its definition of source, byproduct, or special nuclear materials. Examples of materials not covered include radium and accelerator-produced isotopes. See Train v. Colorado Public Interest Research Group, Inc., 426 U.S. 1 (1976).
POTW is defined at § 403.3 of this chapter.
Primary industry category means any industry category listed in the NRDC settlement agreement (Natural Resources Defense Council et al. v. Train, 8 E.R.C. 2120 (D.D.C. 1976), modified 12 E.R.C. 1833 (D.D.C. 1979)); also listed in appendix A of part 122.
Privately owned treatment works means any device or system which is (a) used to treat wastes from any facility whose operator is not the operator of the treatment works and (b) not a “POTW.”
Process wastewater means any water which, during manufacturing or processing, comes into direct contact with or results from the production or use of any raw material, intermediate product, finished product, byproduct, or waste product.
Proposed permit means a State NPDES “permit” prepared after the close of the public comment period (and, when applicable, any public hearing and administrative appeals) which is sent to EPA for review before final issuance by the State. A “proposed permit” is not a “draft permit.”
Publicly owned treatment works is defined at 40 CFR 403.3.
Recommencing discharger means a source which recommences discharge after terminating operations.
Regional Administrator means the Regional Administrator of the appropriate Regional Office of the Environmental Protection Agency or the authorized representative of the Regional Administrator.
Schedule of compliance means a schedule of remedial measures included in a “permit”, including an enforceable sequence of interim requirements (for example, actions, operations, or milestone events) leading to compliance with the CWA and regulations.
Secondary industry category means any industry category which is not a “primary industry category.”
Secretary means the Secretary of the Army, acting through the Chief of Engineers.
Septage means the liquid and solid material pumped from a septic tank, cesspool, or similar domestic sewage treatment system, or a holding tank when the system is cleaned or maintained.
Sewage from vessels means human body wastes and the wastes from toilets and other receptacles intended to receive or retain body wastes that are discharged from vessels and regulated under section 312 of CWA, except that with respect to commercial vessels on the Great Lakes this term includes graywater. For the purposes of this definition, “graywater” means galley, bath, and shower water.
Sewage Sludge means any solid, semi-solid, or liquid residue removed during the treatment of municipal waste water or domestic sewage. Sewage sludge includes, but is not limited to, solids removed during primary, secondary, or advanced waste water treatment, scum, septage, portable toilet pumpings, type III marine sanitation device pumpings (33 CFR part 159), and sewage sludge products. Sewage sludge does not include grit or screenings, or ash generated during the incineration of sewage sludge.
Sewage sludge use or disposal practice means the collection, storage, treatment, transportation, processing, monitoring, use, or disposal of sewage sludge.
Silvicultural point source is defined at § 122.27.
Site means the land or water area where any “facility or activity” is physically located or conducted, including adjacent land used in connection with the facility or activity.
Sludge-only facility means any “treatment works treating domestic sewage” whose methods of sewage sludge use or disposal are subject to regulations promulgated pursuant to section 405(d) of the CWA and is required to obtain a permit under § 122.1(b)(2).
Standards for sewage sludge use or disposal means the regulations promulgated pursuant to section 405(d) of the CWA which govern minimum requirements for sludge quality, management practices, and monitoring and reporting applicable to sewage sludge or the use or disposal of sewage sludge by any person.
State means any of the 50 States, the District of Columbia, Guam, the Commonwealth of Puerto Rico, the Virgin Islands, American Samoa, the Commonwealth of the Northern Mariana Islands, the Trust Territory of the Pacific Islands, or an Indian Tribe as defined in these regulations which meets the requirements of § 123.31 of this chapter.
State Director means the chief administrative officer of any State or interstate agency operating an “approved program,” or the delegated representative of the State Director. If responsibility is divided among two or more State or interstate agencies, “State Director” means the chief administrative officer of the State or interstate agency authorized to perform the particular procedure or function to which reference is made.
State/EPA Agreement means an agreement between the Regional Administrator and the State which coordinates EPA and State activities, responsibilities and programs including those under the CWA programs.
Storm water is defined at § 122.26(b)(13).
Storm water discharge associated with industrial activity is defined at § 122.26(b)(14).
Total dissolved solids means the total dissolved (filterable) solids as determined by use of the method specified in 40 CFR part 136.
Toxic pollutant means any pollutant listed as toxic under section 307(a)(1) or, in the case of “sludge use or disposal practices,” any pollutant identified in regulations implementing section 405(d) of the CWA.
Treatment works treating domestic sewage means a POTW or any other sewage sludge or waste water treatment devices or systems, regardless of ownership (including federal facilities), used in the storage, treatment, recycling, and reclamation of municipal or domestic sewage, including land dedicated for the disposal of sewage sludge. This definition does not include septic tanks or similar devices. For purposes of this definition, “domestic sewage” includes waste and waste water from humans or household operations that are discharged to or otherwise enter a treatment works. In States where there is no approved State sludge management program under section 405(f) of the CWA, the Regional Administrator may designate any person subject to the standards for sewage sludge use and disposal in 40 CFR part 503 as a “treatment works treating domestic sewage,” where he or she finds that there is a potential for adverse effects on public health and the environment from poor sludge quality or poor sludge handling, use or disposal practices, or where he or she finds that such designation is necessary to ensure that such person is in compliance with 40 CFR part 503.
TWTDS means “treatment works treating domestic sewage.”
Upset is defined at § 122.41(n).
Variance means any mechanism or provision under section 301 or 316 of CWA or under 40 CFR part 125, or in the applicable “effluent limitations guidelines” which allows modification to or waiver of the generally applicable effluent limitation requirements or time deadlines of CWA. This includes provisions which allow the establishment of alternative limitations based on fundamentally different factors or on sections 301(c), 301(g), 301(h), 301(i), or 316(a) of CWA.
Waters of the United States or waters of the U.S. means the term as it is defined in § 120.2 of this chapter.
Whole effluent toxicity means the aggregate toxic effect of an effluent measured directly by a toxicity test.
§ 122.3 Exclusions.
The following discharges do not require NPDES permits:
(a) Any discharge of sewage from vessels, effluent from properly functioning marine engines, laundry, shower, and galley sink wastes, or any other discharge incidental to the normal operation of a vessel. This exclusion does not apply to rubbish, trash, garbage, or other such materials discharged overboard; nor to other discharges when the vessel is operating in a capacity other than as a means of transportation such as when used as an energy or mining facility, a storage facility or a seafood processing facility, or when secured to a storage facility or a seafood processing facility, or when secured to the bed of the ocean, contiguous zone or waters of the United States for the purpose of mineral or oil exploration or development.
(b) Discharges of dredged or fill material into waters of the United States which are regulated under section 404 of CWA.
(c) The introduction of sewage, industrial wastes or other pollutants into publicly owned treatment works by indirect dischargers. Plans or agreements to switch to this method of disposal in the future do not relieve dischargers of the obligation to have and comply with permits until all discharges of pollutants to waters of the United States are eliminated. (See also § 122.47(b)). This exclusion does not apply to the introduction of pollutants to privately owned treatment works or to other discharges through pipes, sewers, or other conveyances owned by a State, municipality, or other party not leading to treatment works.
(d) Any discharge in compliance with the instructions of an On-Scene Coordinator pursuant to 40 CFR part 300 (The National Oil and Hazardous Substances Pollution Contingency Plan) or 33 CFR 153.10(e) (Pollution by Oil and Hazardous Substances).
(e) Any introduction of pollutants from non point-source agricultural and silvicultural activities, including storm water runoff from orchards, cultivated crops, pastures, range lands, and forest lands, but not discharges from concentrated animal feeding operations as defined in § 122.23, discharges from concentrated aquatic animal production facilities as defined in § 122.24, discharges to aquaculture projects as defined in § 122.25, and discharges from silvicultural point sources as defined in § 122.27.
(f) Return flows from irrigated agriculture.
(g) Discharges into a privately owned treatment works, except as the Director may otherwise require under § 122.44(m).
(h) [Reserved]
(i) Discharges from a water transfer. Water transfer means an activity that conveys or connects waters of the United States without subjecting the transferred water to intervening industrial, municipal, or commercial use. This exclusion does not apply to pollutants introduced by the water transfer activity itself to the water being transferred.
§ 122.4 Prohibitions (applicable to State NPDES programs, see § 123.25).
No permit may be issued:
(a) When the conditions of the permit do not provide for compliance with the applicable requirements of CWA, or regulations promulgated under CWA;
(b) When the applicant is required to obtain a State or other appropriate certification under section 401 of CWA and § 124.53 and that certification has not been obtained or waived;
(c) By the State Director where the Regional Administrator has objected to issuance of the permit under § 123.44;
(d) When the imposition of conditions cannot ensure compliance with the applicable water quality requirements of all affected States;
(e) When, in the judgment of the Secretary, anchorage and navigation in or on any of the waters of the United States would be substantially impaired by the discharge;
(f) For the discharge of any radiological, chemical, or biological warfare agent or high-level radioactive waste;
(g) For any discharge inconsistent with a plan or plan amendment approved under section 208(b) of CWA;
(h) For any discharge to the territorial sea, the waters of the contiguous zone, or the oceans in the following circumstances:
(1) Before the promulgation of guidelines under section 403(c) of CWA (for determining degradation of the waters of the territorial seas, the contiguous zone, and the oceans) unless the Director determines permit issuance to be in the public interest; or
(2) After promulgation of guidelines under section 403(c) of CWA, when insufficient information exists to make a reasonable judgment whether the discharge complies with them.
(i) To a new source or a new discharger, if the discharge from its construction or operation will cause or contribute to the violation of water quality standards. The owner or operator of a new source or new discharger proposing to discharge into a water segment which does not meet applicable water quality standards or is not expected to meet those standards even after the application of the effluent limitations required by sections 301(b)(1)(A) and 301(b)(1)(B) of CWA, and for which the State or interstate agency has performed a pollutants load allocation for the pollutant to be discharged, must demonstrate, before the close of the public comment period, that:
(1) There are sufficient remaining pollutant load allocations to allow for the discharge; and
(2) The existing dischargers into that segment are subject to compliance schedules designed to bring the segment into compliance with applicable water quality standards. The Director may waive the submission of information by the new source or new discharger required by paragraph (i) of this section if the Director determines that the Director already has adequate information to evaluate the request. An explanation of the development of limitations to meet the criteria of this paragraph (i)(2) is to be included in the fact sheet to the permit under § 124.56(b)(1) of this chapter.
§ 122.5 Effect of a permit.
(a) Applicable to State programs, see § 123.25. (1) Except for any toxic effluent standards and prohibitions imposed under section 307 of the CWA and “standards for sewage sludge use or disposal” under 405(d) of the CWA, compliance with a permit during its term constitutes compliance, for purposes of enforcement, with sections 301, 302, 306, 307, 318, 403, and 405 (a)-(b) of CWA. However, a permit may be modified, revoked and reissued, or terminated during its term for cause as set forth in §§ 122.62 and 122.64.
(2) Compliance with a permit condition which implements a particular “standard for sewage sludge use or disposal” shall be an affirmative defense in any enforcement action brought for a violation of that “standard for sewage sludge use or disposal” pursuant to sections 405(e) and 309 of the CWA.
(b) Applicable to State programs, See § 123.25. The issuance of a permit does not convey any property rights of any sort, or any exclusive privilege.
(c) The issuance of a permit does not authorize any injury to persons or property or invasion of other private rights, or any infringement of State or local law or regulations.
§ 122.6 Continuation of expiring permits.
(a) EPA permits. When EPA is the permit-issuing authority, the conditions of an expired permit continue in force under 5 U.S.C. 558(c) until the effective date of a new permit (see § 124.15) if:
(1) The permittee has submitted a timely application under § 122.21 which is a complete (under § 122.21(e)) application for a new permit; and
(2) The Regional Administrator, through no fault of the permittee does not issue a new permit with an effective date under § 124.15 on or before the expiration date of the previous permit (for example, when issuance is impracticable due to time or resource constraints).
(b) Effect. Permits continued under this section remain fully effective and enforceable.
(c) Enforcement. When the permittee is not in compliance with the conditions of the expiring or expired permit the Regional Administrator may choose to do any or all of the following:
(1) Initiate enforcement action based upon the permit which has been continued;
(2) Issue a notice of intent to deny the new permit under § 124.6. If the permit is denied, the owner or operator would then be required to cease the activities authorized by the continued permit or be subject to enforcement action for operating without a permit;
(3) Issue a new permit under part 124 with appropriate conditions; or
(4) Take other actions authorized by these regulations.
(d) State continuation. (1) An EPA-issued permit does not continue in force beyond its expiration date under Federal law if at that time a State is the permitting authority. States authorized to administer the NPDES program may continue either EPA or State-issued permits until the effective date of the new permits, if State law allows. Otherwise, the facility or activity is operating without a permit from the time of expiration of the old permit to the effective date of the State-issued new permit.
§ 122.7 Confidentiality of information.
(a) In accordance with 40 CFR part 2, any information submitted to EPA pursuant to these regulations may be claimed as confidential by the submitter. Any such claim must be asserted at the time of submission in the manner prescribed on the application form or instructions or, in the case of other submissions, by stamping the words “confidential business information” on each page containing such information. If no claim is made at the time of submission, EPA may make the information available to the public without further notice. If a claim is asserted, the information will be treated in accordance with the procedures in 40 CFR part 2 (Public Information).
(b) Applicable to State programs, see § 123.25. Claims of confidentiality for the following information will be denied:
(1) The name and address of any permit applicant or permittee;
(2) Permit applications, permits, and effluent data.
(c) Applicable to State programs, see § 123.25. Information required by NPDES application forms provided by the Director under § 122.21 may not be claimed confidential. This includes information submitted on the forms themselves and any attachments used to supply information required by the forms.
Subpart B – Permit Application and Special NPDES Program Requirements
§ 122.21 Application for a permit (applicable to State programs, see § 123.25).
(a) Duty to apply. (1) Any person who discharges or proposes to discharge pollutants or who owns or operates a “sludge-only facility” whose sewage sludge use or disposal practice is regulated by part 503 of this chapter, and who does not have an effective permit, except persons covered by general permits under § 122.28, excluded under § 122.3, or a user of a privately owned treatment works unless the Director requires otherwise under § 122.44(m), must submit a complete application to the Director in accordance with this section and part 124 of this chapter. The requirements for concentrated animal feeding operations are described in § 122.23(d).
(2) Application Forms: (i) All applicants for EPA-issued permits must submit applications on EPA permit application forms. More than one application form may be required from a facility depending on the number and types of discharges or outfalls found there. Application forms may be obtained by contacting: U.S. EPA, Mail Code 4203M, 1200 Pennsylvania Ave. NW, Washington, DC 20460 or by visiting http://www.epa.gov/npdes. Applications for EPA-issued permits must be submitted as follows:
(A) All applicants, other than POTWs, TWTDS, vessels, and pesticide applicators must submit Form 1.
(B) Applicants for new and existing POTWs must submit the information contained in paragraph (j) of this section using Form 2A or other form provided by the director.
(C) Applicants for concentrated animal feeding operations or aquatic animal production facilities must submit Form 2B.
(D) Applicants for existing industrial facilities (including manufacturing facilities, commercial facilities, mining activities, and silvicultural activities), must submit Form 2C.
(E) Applicants for new industrial facilities that discharge process wastewater must submit Form 2D.
(F) Applicants for new and existing industrial facilities that discharge only nonprocess wastewater must submit Form 2E.
(G) Applicants for new and existing facilities whose discharge is composed entirely of storm water associated with industrial activity must submit Form 2F, unless exempted by § 122.26(c)(1)(ii). If the discharge is composed of storm water and non-storm water, the applicant must also submit, Forms 2C, 2D, and/or 2E, as appropriate (in addition to Form 2F).
(H) Applicants for new and existing TWTDS, subject to paragraph (c)(2)(i) of this section must submit the application information required by paragraph (q) of this section, using Form 2S or other form provided by the director.
(ii) The application information required by paragraph (a)(2)(i) of this section may be electronically submitted if such method of submittal is approved by EPA or the Director.
(iii) Applicants can obtain copies of these forms by contacting the Water Management Divisions (or equivalent division which contains the NPDES permitting function) of the EPA Regional Offices. The Regional Offices’ addresses can be found at § 1.7 of this chapter.
(iv) Applicants for State-issued permits must use State forms which must require at a minimum the information listed in the appropriate paragraphs of this section.
(b) Who applies? When a facility or activity is owned by one person but is operated by another person, it is the operator’s duty to obtain a permit.
(c) Time to apply. (1) Any person proposing a new discharge, shall submit an application at least 180 days before the date on which the discharge is to commence, unless permission for a later date has been granted by the Director. Facilities proposing a new discharge of storm water associated with industrial activity shall submit an application 180 days before that facility commences industrial activity which may result in a discharge of storm water associated with that industrial activity. Facilities described under § 122.26(b)(14)(x) or (b)(15)(i) shall submit applications at least 90 days before the date on which construction is to commence. Different submittal dates may be required under the terms of applicable general permits. Persons proposing a new discharge are encouraged to submit their applications well in advance of the 90 or 180 day requirements to avoid delay. See also paragraph (k) of this section and § 122.26(c)(1)(i)(G) and (c)(1)(ii).
(2) Permits under section 405(f) of CWA. All TWTDS whose sewage sludge use or disposal practices are regulated by part 503 of this chapter must submit permit applications according to the applicable schedule in paragraphs (c)(2)(i) or (ii) of this section.
(i) A TWTDS with a currently effective NPDES permit must submit a permit application at the time of its next NPDES permit renewal application. Such information must be submitted in accordance with paragraph (d) of this section.
(ii) Any other TWTDS not addressed under paragraph (c)(2)(i) of this section must submit the information listed in paragraphs (c)(2)(ii)(A) through (E) of this section to the Director within 1 year after publication of a standard applicable to its sewage sludge use or disposal practice(s), using Form 2S or another form provided by the Director. The Director will determine when such TWTDS must submit a full permit application.
(A) The TWTDS’s name, mailing address, location, and status as federal, State, private, public or other entity;
(B) The applicant’s name, address, telephone number, electronic mail address and ownership status;
(C) A description of the sewage sludge use or disposal practices. Unless the sewage sludge meets the requirements of paragraph (q)(8)(iv) of this section, the description must include the name and address of any facility where sewage sludge is sent for treatment or disposal, and the location of any land application sites;
(D) Annual amount of sewage sludge generated, treated, used or disposed (estimated dry weight basis); and
(E) The most recent data the TWTDS may have on the quality of the sewage sludge.
(iii) Notwithstanding paragraphs (c)(2)(i) or (ii) of this section, the Director may require permit applications from any TWTDS at any time if the Director determines that a permit is necessary to protect public health and the environment from any potential adverse effects that may occur from toxic pollutants in sewage sludge.
(iv) Any TWTDS that commences operations after promulgation of an applicable “standard for sewage sludge use or disposal” must submit an application to the Director at least 180 days prior to the date proposed for commencing operations.
(d) Duty to reapply. (1) Any POTW with a currently effective permit shall submit a new application at least 180 days before the expiration date of the existing permit, unless permission for a later date has been granted by the Director. (The Director shall not grant permission for applications to be submitted later than the expiration date of the existing permit.)
(2) All other permittees with currently effective permits shall submit a new application 180 days before the existing permit expires, except that:
(i) The Regional Administrator may grant permission to submit an application later than the deadline for submission otherwise applicable, but no later than the permit expiration date; and
(3) [Reserved]
(e) Completeness. (1) The Director shall not issue a permit before receiving a complete application for a permit except for NPDES general permits. An application for a permit is complete when the Director receives an application form and any supplemental information which are completed to his or her satisfaction. The completeness of any application for a permit shall be judged independently of the status of any other permit application or permit for the same facility or activity. For EPA administered NPDES programs, an application which is reviewed under § 124.3 of this chapter is complete when the Director receives either a complete application or the information listed in a notice of deficiency.
(2) A permit application shall not be considered complete if a permitting authority has waived application requirements under paragraphs (j) or (q) of this section and EPA has disapproved the waiver application. If a waiver request has been submitted to EPA more than 210 days prior to permit expiration and EPA has not disapproved the waiver application 181 days prior to permit expiration, the permit application lacking the information subject to the waiver application shall be considered complete.
(3) Except as specified in 122.21(e)(3)(ii), a permit application shall not be considered complete unless all required quantitative data are collected in accordance with sufficiently sensitive analytical methods approved under 40 CFR part 136 or required under 40 CFR chapter I, subchapter N or O.
(i) For the purposes of this requirement, a method approved under 40 CFR part 136 or required under 40 CFR chapter I, subchapter N or O is “sufficiently sensitive” when:
(A) The method minimum level (ML) is at or below the level of the applicable water quality criterion for the measured pollutant or pollutant parameter; or
(B) The method ML is above the applicable water quality criterion, but the amount of the pollutant or pollutant parameter in a facility’s discharge is high enough that the method detects and quantifies the level of the pollutant or pollutant parameter in the discharge; or
(C) The method has the lowest ML of the analytical methods approved under 40 CFR part 136 or required under 40 CFR chapter I, subchapter N or O for the measured pollutant or pollutant parameter.
Consistent with 40 CFR part 136, applicants have the option of providing matrix or sample specific minimum levels rather than the published levels. Further, where an applicant can demonstrate that, despite a good faith effort to use a method that would otherwise meet the definition of “sufficiently sensitive”, the analytical results are not consistent with the QA/QC specifications for that method, then the Director may determine that the method is not performing adequately and the applicant should select a different method from the remaining EPA-approved methods that is sufficiently sensitive consistent with 40 CFR 122.21(e)(3)(i). Where no other EPA-approved methods exist, the applicant should select a method consistent with 40 CFR 122.21(e)(3)(ii).
(ii) When there is no analytical method that has been approved under 40 CFR part 136, required under 40 CFR chapter I, subchapter N or O, and is not otherwise required by the Director, the applicant may use any suitable method but shall provide a description of the method. When selecting a suitable method, other factors such as a method’s precision, accuracy, or resolution, may be considered when assessing the performance of the method.
(f) Information requirements. All applicants for NPDES permits, other than POTWs and other TWTDS, vessels, and pesticide applicators, must provide the information in paragraphs (f)(1) through (10) of this section to the Director, using the application form provided by the Director. Additional information required of applicants is set forth in paragraphs (g) through (k) and (q) through (r) of this section.
(1) The activities conducted by the applicant which require it to obtain an NPDES permit.
(2) Name, mailing address, and location of the facility for which the application is submitted.
(3) Up to four SIC and up to four NAICS codes that best reflect the principal products or services provided by the facility.
(4) The operator’s name, address, telephone number, electronic mail address, ownership status, and status as Federal, State, private, public, or other entity.
(5) Whether the facility is located on Indian lands.
(6) A listing of all permits or construction approvals received or applied for under any of the following programs:
(i) Hazardous Waste Management program under RCRA.
(ii) UIC program under SDWA.
(iii) NPDES program under CWA.
(iv) Prevention of Significant Deterioration (PSD) program under the Clean Air Act.
(v) Nonattainment program under the Clean Air Act.
(vi) National Emission Standards for Hazardous Pollutants (NESHAPS) preconstruction approval under the Clean Air Act.
(vii) Ocean dumping permits under the Marine Protection Research and Sanctuaries Act.
(viii) Dredge or fill permits under section 404 of CWA.
(ix) Other relevant environmental permits, including State permits.
(7) A topographic map (or other map if a topographic map is unavailable) extending one mile beyond the property boundaries of the source, depicting the facility and each of its intake and discharge structures; each of its hazardous waste treatment, storage, or disposal facilities; each well where fluids from the facility are injected underground; and those wells, springs, other surface water bodies, and drinking water wells listed in public records or otherwise known to the applicant in the map area.
(8) A brief description of the nature of the business.
(9) An indication of whether the facility uses cooling water and the source of the cooling water.
(10) An indication of whether the facility is requesting any of the variances at 40 CFR 122.21(m), if known at the time of application.
(g) Application requirements for existing manufacturing, commercial, mining, and silvicultural dischargers. Existing manufacturing, commercial, mining, and silvicultural dischargers applying for NPDES permits, except for those facilities subject to the requirements of § 122.21(h), shall provide the following information to the Director, using application forms provided by the Director.
(1) Outfall location. The latitude and longitude to the nearest 15 seconds and the name of the receiving water.
(2) Line drawing. A line drawing of the water flow through the facility with a water balance, showing operations contributing wastewater to the effluent and treatment units. Similar processes, operations, or production areas may be indicated as a single unit, labeled to correspond to the more detailed identification under paragraph (g)(3) of this section. The water balance must show approximate average flows at intake and discharge points and between units, including treatment units. If a water balance cannot be determined (for example, for certain mining activities), the applicant may provide instead a pictorial description of the nature and amount of any sources of water and any collection and treatment measures.
(3) Average flows and treatment. A narrative identification of each type of process, operation, or production area which contributes wastewater to the effluent for each outfall, including process wastewater, cooling water, and stormwater runoff; the average flow which each process contributes; and a description of the treatment the wastewater receives, including the ultimate disposal of any solid or fluid wastes other than by discharge. Processes, operations, or production areas may be described in general terms (for example, “dye-making reactor”, “distillation tower”). For a privately owned treatment works, this information shall include the identity of each user of the treatment works. The average flow of point sources composed of storm water may be estimated. The basis for the rainfall event and the method of estimation must be indicated.
(4) Intermittent flows. If any of the discharges described in paragraph (g)(3) of this section are intermittent or seasonal, a description of the frequency, duration and flow rate of each discharge occurrence (except for stormwater runoff, spillage or leaks).
(5) Maximum production. If an effluent guideline promulgated under section 304 of CWA applies to the applicant and is expressed in terms of production (or other measure of operation), a reasonable measure of the applicant’s actual production reported in the units used in the applicable effluent guideline. The reported measure must reflect the actual production of the facility as required by § 122.45(b)(2).
(6) Improvements. If the applicant is subject to any present requirements or compliance schedules for construction, upgrading or operation of waste treatment equipment, an identification of the abatement requirement, a description of the abatement project, and a listing of the required and projected final compliance dates.
(7) Effluent characteristics. (i) Information on the discharge of pollutants specified in this paragraph (g)(7) (except information on storm water discharges which is to be provided as specified in § 122.26). When “quantitative data” for a pollutant are required, the applicant must collect a sample of effluent and analyze it for the pollutant in accordance with analytical methods approved under Part 136 of this chapter unless use of another method is required for the pollutant under 40 CFR subchapters N or O. When no analytical method is approved under Part 136 or required under subchapters N or O, the applicant may use any suitable method but must provide a description of the method. When an applicant has two or more outfalls with substantially identical effluents, the Director may allow the applicant to test only one outfall and report that quantitative data as applying to the substantially identical outfall. The requirements in paragraphs (g)(7)(vi) and (vii) of this section state that an applicant must provide quantitative data for certain pollutants known or believed to be present do not apply to pollutants present in a discharge solely as the result of their presence in intake water; however, an applicant must report such pollutants as present. When paragraph (g)(7) of this section requires analysis of pH, temperature, cyanide, total phenols, residual chlorine, oil and grease, fecal coliform (including E. coli), and Enterococci (previously known as fecal streptococcus at § 122.26 (d)(2)(iii)(A)(3)), or volatile organics, grab samples must be collected for those pollutants. For all other pollutants, a 24-hour composite sample, using a minimum of four (4) grab samples, must be used unless specified otherwise at 40 CFR Part 136. However, a minimum of one grab sample may be taken for effluents from holding ponds or other impoundments with a retention period greater than 24 hours. In addition, for discharges other than storm water discharges, the Director may waive composite sampling for any outfall for which the applicant demonstrates that the use of an automatic sampler is infeasible and that the minimum of four (4) grab samples will be a representative sample of the effluent being discharged. Results of analyses of individual grab samples for any parameter may be averaged to obtain the daily average. Grab samples that are not required to be analyzed immediately (see Table II at 40 CFR 136.3 (e)) may be composited in the laboratory, provided that container, preservation, and holding time requirements are met (see Table II at 40 CFR 136.3 (e)) and that sample integrity is not compromised by compositing.
(ii) Storm water discharges. For storm water discharges, all samples shall be collected from the discharge resulting from a storm event that is greater than 0.1 inch and at least 72 hours from the previously measurable (greater than 0.1 inch rainfall) storm event. Where feasible, the variance in the duration of the event and the total rainfall of the event should not exceed 50 percent from the average or median rainfall event in that area. For all applicants, a flow-weighted composite shall be taken for either the entire discharge or for the first three hours of the discharge. The flow-weighted composite sample for a storm water discharge may be taken with a continuous sampler or as a combination of a minimum of three sample aliquots taken in each hour of discharge for the entire discharge or for the first three hours of the discharge, with each aliquot being separated by a minimum period of fifteen minutes (applicants submitting permit applications for storm water discharges under § 122.26(d) may collect flow-weighted composite samples using different protocols with respect to the time duration between the collection of sample aliquots, subject to the approval of the Director). However, a minimum of one grab sample may be taken for storm water discharges from holding ponds or other impoundments with a retention period greater than 24 hours. For a flow-weighted composite sample, only one analysis of the composite of aliquots is required. For storm water discharge samples taken from discharges associated with industrial activities, quantitative data must be reported for the grab sample taken during the first thirty minutes (or as soon thereafter as practicable) of the discharge for all pollutants specified in § 122.26(c)(1). For all storm water permit applicants taking flow-weighted composites, quantitative data must be reported for all pollutants specified in § 122.26 except pH, temperature, cyanide, total phenols, residual chlorine, oil and grease, fecal coliform, and fecal streptococcus. The Director may allow or establish appropriate site-specific sampling procedures or requirements, including sampling locations, the season in which the sampling takes place, the minimum duration between the previous measurable storm event and the storm event sampled, the minimum or maximum level of precipitation required for an appropriate storm event, the form of precipitation sampled (snow melt or rain fall), protocols for collecting samples under part 136 of this chapter, and additional time for submitting data on a case-by-case basis. An applicant is expected to “know or have reason to believe” that a pollutant is present in an effluent based on an evaluation of the expected use, production, or storage of the pollutant, or on any previous analyses for the pollutant. (For example, any pesticide manufactured by a facility may be expected to be present in contaminated storm water runoff from the facility.)
(iii) Reporting requirements. Every applicant must report quantitative data for every outfall for the following pollutants:
(iv) The Director may waive the reporting requirements for individual point sources or for a particular industry category for one or more of the pollutants listed in paragraph (g)(7)(iii) of this section if the applicant has demonstrated that such a waiver is appropriate because information adequate to support issuance of a permit can be obtained with less stringent requirements.
(v) Each applicant with processes in one or more primary industry category (see appendix A of this part) contributing to a discharge must report quantitative data for the following pollutants in each outfall containing process wastewater:
(A) The organic toxic pollutants in the fractions designated in table I of appendix D of this part for the applicant’s industrial category or categories unless the applicant qualifies as a small business under paragraph (g)(8) of this section. Table II of appendix D of this part lists the organic toxic pollutants in each fraction. The fractions result from the sample preparation required by the analytical procedure which uses gas chromatography/mass spectrometry. A determination that an applicant falls within a particular industrial category for the purposes of selecting fractions for testing is not conclusive as to the applicant’s inclusion in that category for any other purposes. See Notes 2, 3, and 4 of this section.
(B) The pollutants listed in table III of appendix D of this part (the toxic metals, cyanide, and total phenols).
(vi)(A) Each applicant must indicate whether it knows or has reason to believe that any of the pollutants in table IV of appendix D of this part (certain conventional and nonconventional pollutants) is discharged from each outfall. If an applicable effluent limitations guideline either directly limits the pollutant or, by its express terms, indirectly limits the pollutant through limitations on an indicator, the applicant must report quantitative data. For every pollutant discharged which is not so limited in an effluent limitations guideline, the applicant must either report quantitative data or briefly describe the reasons the pollutant is expected to be discharged.
(B) Each applicant must indicate whether it knows or has reason to believe that any of the pollutants listed in table II or table III of appendix D of this part (the toxic pollutants and total phenols) for which quantitative data are not otherwise required under paragraph (g)(7)(v) of this section are discharged from each outfall. For every pollutant expected to be discharged in concentrations of 10 ppb or greater the applicant must report quantitative data. For acrolein, acrylonitrile, 2,4 dinitrophenol, and 2-methyl-4, 6 dinitrophenol, where any of these four pollutants are expected to be discharged in concentrations of 100 ppb or greater the applicant must report quantitative data. For every pollutant expected to be discharged in concentrations less than 10 ppb, or in the case of acrolein, acrylonitrile, 2,4 dinitrophenol, and 2-methyl-4, 6 dinitrophenol, in concentrations less than 100 ppb, the applicant must either submit quantitative data or briefly describe the reasons the pollutant is expected to be discharged. An applicant qualifying as a small business under paragraph (g)(8) of this section is not required to analyze for pollutants listed in table II of appendix D of this part (the organic toxic pollutants).
(vii) Each applicant must indicate whether it knows or has reason to believe that any of the pollutants in table V of appendix D of this part (certain hazardous substances and asbestos) are discharged from each outfall. For every pollutant expected to be discharged, the applicant must briefly describe the reasons the pollutant is expected to be discharged, and report any quantitative data it has for any pollutant.
(viii) Each applicant must report qualitative data, generated using a screening procedure not calibrated with analytical standards, for 2,3,7,8-tetrachlorodibenzo-p-dioxin (TCDD) if it:
(A) Uses or manufactures 2,4,5-trichlorophenoxy acetic acid (2,4,5,-T); 2-(2,4,5-trichlorophenoxy) propanoic acid (Silvex, 2,4,5,-TP); 2-(2,4,5-trichlorophenoxy) ethyl, 2,2-dichloropropionate (Erbon); O,O-dimethyl O-(2,4,5-trichlorophenyl) phosphorothioate (Ronnel); 2,4,5-trichlorophenol (TCP); or hexachlorophene (HCP); or
(B) Knows or has reason to believe that TCDD is or may be present in an effluent.
(ix) Where quantitative data are required in paragraphs (g)(7)(i) through (viii) of this section, existing data may be used, if available, in lieu of sampling done solely for the purpose of the application, provided that: All data requirements are met; sampling was performed, collected, and analyzed no more than four and one-half years prior to submission; all data are representative of the discharge; and all available representative data are considered in the values reported.
(8) Small business exemption. An application which qualifies as a small business under one of the following criteria is exempt from the requirements in paragraph (g)(7)(v)(A) or (g)(7)(vi)(A) of this section to submit quantitative data for the pollutants listed in table II of appendix D of this part (the organic toxic pollutants):
(i) For coal mines, a probable total annual production of less than 100,000 tons per year.
(ii) For all other applicants, gross total annual sales averaging less than $100,000 per year (in second quarter 1980 dollars).
(9) Used or manufactured toxics. A listing of any toxic pollutant which the applicant currently uses or manufactures as an intermediate or final product or byproduct. The Director may waive or modify this requirement for any applicant if the applicant demonstrates that it would be unduly burdensome to identify each toxic pollutant and the Director has adequate information to issue the permit.
(10) [Reserved]
(11) Biological toxicity tests. An identification of any biological toxicity tests which the applicant knows or has reason to believe have been made within the last 3 years on any of the applicant’s discharges or on a receiving water in relation to a discharge.
(12) Contract analyses. If a contract laboratory or consulting firm performed any of the analyses required by paragraph (g)(7) of this section, the identity of each laboratory or firm and the analyses performed.
(13) Additional information. In addition to the information reported on the application form, applicants shall provide to the Director, at his or her request, such other information as the Director may reasonably require to assess the discharges of the facility and to determine whether to issue an NPDES permit. The additional information may include additional quantitative data and bioassays to assess the relative toxicity of discharges to aquatic life and requirements to determine the cause of the toxicity.
(h) Application requirements for manufacturing, commercial, mining and silvicultural facilities which discharge only non-process wastewater. Except for stormwater discharges, all manufacturing, commercial, mining and silvicultural dischargers applying for NPDES permits which discharge only non-process wastewater not regulated by an effluent limitations guideline or new source performance standard shall provide the following information to the Director, using application forms provided by the Director:
(1) Outfall location. Outfall number, latitude and longitude to the nearest 15 seconds, and the name of the receiving water.
(2) Discharge date (for new dischargers). Date of expected commencement of discharge.
(3) Type of waste. An identification of the general type of waste discharged, or expected to be discharged upon commencement of operations, including sanitary wastes, restaurant or cafeteria wastes, or noncontact cooling water. An identification of cooling water additives (if any) that are used or expected to be used upon commencement of operations, along with their composition if existing composition is available.
(4) Effluent characteristics. (i) Quantitative data for the pollutants or parameters listed below, unless testing is waived by the Director. The quantitative data may be data collected over the past 365 days, if they remain representative of current operations, and must include maximum daily value, average daily value, and number of measurements taken. The applicant must collect and analyze samples in accordance with 40 CFR Part 136. When analysis of pH, temperature, residual chlorine, oil and grease, or fecal coliform (including E. coli), and Enterococci (previously known as fecal streptococcus) and volatile organics is required in paragraphs (h)(4)(i)(A) through (K) of this section, grab samples must be collected for those pollutants. For all other pollutants, a 24-hour composite sample, using a minimum of four (4) grab samples, must be used unless specified otherwise at 40 CFR Part 136. For a composite sample, only one analysis of the composite of aliquots is required. New dischargers must include estimates for the pollutants or parameters listed below instead of actual sampling data, along with the source of each estimate. All levels must be reported or estimated as concentration and as total mass, except for flow, pH, and temperature.
(A) Biochemical Oxygen Demand (BOD
(B) Total Suspended Solids (TSS).
(C) Fecal Coliform (if believed present or if sanitary waste is or will be discharged).
(D) Total Residual Chlorine (if chlorine is used).
(E) Oil and Grease.
(F) Chemical Oxygen Demand (COD) (if non-contact cooling water is or will be discharged).
(G) Total Organic Carbon (TOC) (if non-contact cooling water is or will be discharged).
(H) Ammonia (as N).
(I) Discharge Flow.
(J) pH.
(K) Temperature (Winter and Summer).
(ii) The Director may waive the testing and reporting requirements for any of the pollutants or flow listed in paragraph (h)(4)(i) of this section if the applicant submits a request for such a waiver before or with his application which demonstrates that information adequate to support issuance of a permit can be obtained through less stringent requirements.
(iii) If the applicant is a new discharger, he must complete and submit Item IV of Form 2e (see § 122.21(h)(4)) by providing quantitative data in accordance with that section no later than two years after commencement of discharge. However, the applicant need not complete those portions of Item IV requiring tests which he has already performed and reported under the discharge monitoring requirements of his NPDES permit.
(iv) The requirements of parts i and iii of this section that an applicant must provide quantitative data or estimates of certain pollutants do not apply to pollutants present in a discharge solely as a result of their presence in intake water. However, an applicant must report such pollutants as present. Net credit may be provided for the presence of pollutants in intake water if the requirements of § 122.45(g) are met.
(5) Flow. A description of the frequency of flow and duration of any seasonal or intermittent discharge (except for stormwater runoff, leaks, or spills).
(6) Treatment system. A brief description of any system used or to be used.
(7) Optional information. Any additional information the applicant wishes to be considered, such as influent data for the purpose of obtaining “net” credits pursuant to § 122.45(g).
(8) Certification. Signature of certifying official under § 122.22.
(i) Application requirements for new and existing concentrated animal feeding operations and aquatic animal production facilities. New and existing concentrated animal feeding operations (defined in § 122.23) and concentrated aquatic animal production facilities (defined in § 122.24) shall provide the following information to the Director, using the application form provided by the Director:
(1) For concentrated animal feeding operations:
(i) The name of the owner or operator;
(ii) The facility location and mailing addresses;
(iii) Latitude and longitude of the production area (entrance to production area);
(iv) A topographic map of the geographic area in which the CAFO is located showing the specific location of the production area, in lieu of the requirements of paragraph (f)(7) of this section;
(v) Specific information about the number and type of animals, whether in open confinement or housed under roof (beef cattle, broilers, layers, swine weighing 55 pounds or more, swine weighing less than 55 pounds, mature dairy cows, dairy heifers, veal calves, sheep and lambs, horses, ducks, turkeys, other);
(vi) The type of containment and storage (anaerobic lagoon, roofed storage shed, storage ponds, underfloor pits, above ground storage tanks, below ground storage tanks, concrete pad, impervious soil pad, other) and total capacity for manure, litter, and process wastewater storage(tons/gallons);
(vii) The total number of acres under control of the applicant available for land application of manure, litter, or process wastewater;
(viii) Estimated amounts of manure, litter, and process wastewater generated per year (tons/gallons);
(ix) Estimated amounts of manure, litter and process wastewater transferred to other persons per year (tons/gallons); and
(x) A nutrient management plan that at a minimum satisfies the requirements specified in § 122.42(e), including, for all CAFOs subject to 40 CFR part 412, subpart C or subpart D, the requirements of 40 CFR 412.4(c), as applicable.
(2) For concentrated aquatic animal production facilities:
(i) The maximum daily and average monthly flow from each outfall.
(ii) The number of ponds, raceways, and similar structures.
(iii) The name of the receiving water and the source of intake water.
(iv) For each species of aquatic animals, the total yearly and maximum harvestable weight.
(v) The calendar month of maximum feeding and the total mass of food fed during that month.
(j) Application requirements for new and existing POTWs. Unless otherwise indicated, all POTWs and other dischargers designated by the Director must provide, at a minimum, the information in this paragraph to the Director, using Form 2A or another application form provided by the Director. Permit applicants must submit all information available at the time of permit application. The information may be provided by referencing information previously submitted to the Director. The Director may waive any requirement of this paragraph if he or she has access to substantially identical information. The Director may also waive any requirement of this paragraph that is not of material concern for a specific permit, if approved by the Regional Administrator. The waiver request to the Regional Administrator must include the State’s justification for the waiver. A Regional Administrator’s disapproval of a State’s proposed waiver does not constitute final Agency action, but does provide notice to the State and permit applicant(s) that EPA may object to any State-issued permit issued in the absence of the required information.
(1) Basic application information. All applicants must provide the following information:
(i) Facility information. Name, mailing address, and location of the facility for which the application is submitted;
(ii) Applicant information. Name, mailing address, telephone number, and electronic mail address of the applicant, and indication as to whether the applicant is the facility’s owner, operator, or both;
(iii) Existing environmental permits. Identification of all environmental permits or construction approvals received or applied for (including dates) under any of the following programs:
(A) Hazardous Waste Management program under the Resource Conservation and Recovery Act (RCRA), Subpart C;
(B) Underground Injection Control program under the Safe Drinking Water Act (SDWA);
(C) NPDES program under Clean Water Act (CWA);
(D) Prevention of Significant Deterioration (PSD) program under the Clean Air Act;
(E) Nonattainment program under the Clean Air Act;
(F) National Emission Standards for Hazardous Air Pollutants (NESHAPS) preconstruction approval under the Clean Air Act;
(G) Ocean dumping permits under the Marine Protection Research and Sanctuaries Act;
(H) Dredge or fill permits under section 404 of the CWA; and
(I) Other relevant environmental permits, including State permits;
(iv) Population. The name and population of each municipal entity served by the facility, including unincorporated connector districts. Indicate whether each municipal entity owns or maintains the collection system and whether the collection system is separate sanitary or combined storm and sanitary, if known;
(v) Indian country. Information concerning whether the facility is located in Indian country and whether the facility discharges to a receiving stream that flows through Indian country;
(vi) Flow rate. The facility’s design flow rate (the wastewater flow rate the plant was built to handle), annual average daily flow rate, and maximum daily flow rate for each of the previous 3 years;
(vii) Collection system. Identification of type(s) of collection system(s) used by the treatment works (i.e., separate sanitary sewers or combined storm and sanitary sewers) and an estimate of the percent of sewer line that each type comprises; and
(viii) Outfalls and other discharge or disposal methods. The following information for outfalls to waters of the United States and other discharge or disposal methods:
(A) For effluent discharges to waters of the United States, the total number and types of outfalls (e.g, treated effluent, combined sewer overflows, bypasses, constructed emergency overflows);
(B) For wastewater discharged to surface impoundments:
(1) The location of each surface impoundment;
(2) The average daily volume discharged to each surface impoundment; and
(3) Whether the discharge is continuous or intermittent;
(C) For wastewater applied to the land:
(1) The location of each land application site;
(2) The size of each land application site, in acres;
(3) The average daily volume applied to each land application site, in gallons per day; and
(4) Whether land application is continuous or intermittent;
(D) For effluent sent to another facility for treatment prior to discharge:
(1) The means by which the effluent is transported;
(2) The name, mailing address, contact person, phone number, and electronic mail address of the organization transporting the discharge, if the transport is provided by a party other than the applicant;
(3) The name, mailing address, contact person, phone number, electronic mail address and NPDES permit number (if any) of the receiving facility; and
(4) The average daily flow rate from this facility into the receiving facility, in millions of gallons per day; and
(E) For wastewater disposed of in a manner not included in paragraphs (j)(1)(viii)(A) through (D) of this section (e.g., underground percolation, underground injection):
(1) A description of the disposal method, including the location and size of each disposal site, if applicable;
(2) The annual average daily volume disposed of by this method, in gallons per day; and
(3) Whether disposal through this method is continuous or intermittent;
(ix) An indication of whether applicant is operating under or requesting to operate under a variance as specified at 40 CFR 122.21(n), if known at the time of application.
(2) Additional Information. All applicants with a design flow greater than or equal to 0.1 mgd must provide the following information:
(i) Inflow and infiltration. The current average daily volume of inflow and infiltration, in gallons per day, and steps the facility is taking to minimize inflow and infiltration;
(ii) Topographic map. A topographic map (or other map if a topographic map is unavailable) extending at least one mile beyond property boundaries of the treatment plant, including all unit processes, and showing:
(A) Treatment plant area and unit processes;
(B) The major pipes or other structures through which wastewater enters the treatment plant and the pipes or other structures through which treated wastewater is discharged from the treatment plant. Include outfalls from bypass piping, if applicable;
(C) Each well where fluids from the treatment plant are injected underground;
(D) Wells, springs, and other surface water bodies listed in public records or otherwise known to the applicant within
(E) Sewage sludge management facilities (including on-site treatment, storage, and disposal sites); and
(F) Location at which waste classified as hazardous under RCRA enters the treatment plant by truck, rail, or dedicated pipe;
(iii) Process flow diagram or schematic. (A) A diagram showing the processes of the treatment plant, including all bypass piping and all backup power sources or redundancy in the system. This includes a water balance showing all treatment units, including disinfection, and showing daily average flow rates at influent and discharge points, and approximate daily flow rates between treatment units; and
(B) A narrative description of the diagram; and
(iv) Scheduled improvements, schedules of implementation. The following information regarding scheduled improvements:
(A) The outfall number of each outfall affected;
(B) A narrative description of each required improvement;
(C) Scheduled or actual dates of completion for the following:
(1) Commencement of construction;
(2) Completion of construction;
(3) Commencement of discharge; and
(4) Attainment of operational level;
(D) A description of permits and clearances concerning other Federal and/or State requirements;
(3) Information on effluent discharges. Each applicant must provide the following information for each outfall, including bypass points, through which effluent is discharged, as applicable:
(i) Description of outfall. The following information about each outfall:
(A) Outfall number;
(B) State, county, and city or town in which outfall is located;
(C) Latitude and longitude, to the nearest second;
(D) Distance from shore and depth below surface;
(E) Average daily flow rate, in million gallons per day;
(F) The following information for each outfall with a seasonal or periodic discharge:
(1) Number of times per year the discharge occurs;
(2) Duration of each discharge;
(3) Flow of each discharge; and
(4) Months in which discharge occurs; and
(G) Whether the outfall is equipped with a diffuser and the type (e.g., high-rate) of diffuser used;
(ii) Description of receiving waters. The following information (if known) for each outfall through which effluent is discharged to waters of the United States:
(A) Name of receiving water;
(B) Name of watershed/river/stream system and United States Soil Conservation Service 14-digit watershed code;
(C) Name of State Management/River Basin and United States Geological Survey 8-digit hydrologic cataloging unit code; and
(D) Critical flow of receiving stream and total hardness of receiving stream at critical low flow (if applicable);
(iii) Description of treatment. The following information describing the treatment provided for discharges from each outfall to waters of the United States:
(A) The highest level of treatment (e.g., primary, equivalent to secondary, secondary, advanced, other) that is provided for the discharge for each outfall and:
(1) Design biochemical oxygen demand (BOD
(2) Design suspended solids (SS) removal (percent); and, where applicable,
(3) Design phosphorus (P) removal (percent);
(4) Design nitrogen (N) removal (percent); and
(5) Any other removals that an advanced treatment system is designed to achieve.
(B) A description of the type of disinfection used, and whether the treatment plant dechlorinates (if disinfection is accomplished through chlorination);
(4) Effluent monitoring for specific parameters. (i) As provided in paragraphs (j)(4)(ii) through (x) of this section, all applicants must submit to the Director effluent monitoring information for samples taken from each outfall through which effluent is discharged to waters of the United States, except for CSOs. The Director may allow applicants to submit sampling data for only one outfall on a case-by-case basis, where the applicant has two or more outfalls with substantially identical effluent. The Director may also allow applicants to composite samples from one or more outfalls that discharge into the same mixing zone. For POTWs applying prior to commencement of discharge, data shall be submitted no later than 24 months after the commencement of discharge;
(ii) All applicants must sample and analyze for the pollutants listed in appendix J, Table 1A of this part;
(iii) All applicants with a design flow greater than or equal to 0.1 mgd must sample and analyze for the pollutants listed in appendix J, Table 1 of this part. Facilities that do not use chlorine for disinfection, do not use chlorine elsewhere in the treatment process, and have no reasonable potential to discharge chlorine in their effluent may delete chlorine from Table 1;
(iv) The following applicants must sample and analyze for the pollutants listed in appendix J, Table 2 of this part, and for any other pollutants for which the State or EPA have established water quality standards applicable to the receiving waters:
(A) All POTWs with a design flow rate equal to or greater than one million gallons per day;
(B) All POTWs with approved pretreatment programs or POTWs required to develop a pretreatment program;
(C) Other POTWs, as required by the Director;
(v) The Director should require sampling for additional pollutants, as appropriate, on a case-by-case basis;
(vi) Applicants must provide data from a minimum of three samples taken within four and one-half years prior to the date of the permit application. Samples must be representative of the seasonal variation in the discharge from each outfall. Existing data may be used, if available, in lieu of sampling done solely for the purpose of this application. The Director should require additional samples, as appropriate, on a case-by-case basis.
(vii) All existing data for pollutants specified in paragraphs (j)(4)(ii) through (v) of this section that is collected within four and one-half years of the application must be included in the pollutant data summary submitted by the applicant. If, however, the applicant samples for a specific pollutant on a monthly or more frequent basis, it is only necessary, for such pollutant, to summarize all data collected within one year of the application.
(viii) Applicants must collect samples of effluent and analyze such samples for pollutants in accordance with analytical methods approved under 40 CFR Part 136 unless an alternative is specified in the existing NPDES permit. When analysis of pH, temperature, cyanide, total phenols, residual chlorine, oil and grease, fecal coliform (including E. coli), or volatile organics is required in paragraphs (j)(4)(ii) through (iv) of this section, grab samples must be collected for those pollutants. For all other pollutants, 24-hour composite samples must be used. For a composite sample, only one analysis of the composite of aliquots is required.
(ix) The effluent monitoring data provided must include at least the following information for each parameter:
(A) Maximum daily discharge, expressed as concentration or mass, based upon actual sample values;
(B) Average daily discharge for all samples, expressed as concentration or mass, and the number of samples used to obtain this value;
(C) The analytical method used; and
(D) The threshold level (i.e., method detection limit, minimum level, or other designated method endpoints) for the analytical method used.
(x) Unless otherwise required by the Director, metals must be reported as total recoverable.
(5) Effluent monitoring for whole effluent toxicity. (i) All applicants must provide an identification of any whole effluent toxicity tests conducted during the four and one-half years prior to the date of the application on any of the applicant’s discharges or on any receiving water near the discharge. For POTWs applying prior to commencement of discharge, data shall be submitted no later than 24 months after the commencement of discharge.
(ii) As provided in paragraphs (j)(5)(iii)-(ix) of this section, the following applicants must submit to the Director the results of valid whole effluent toxicity tests for acute or chronic toxicity for samples taken from each outfall through which effluent is discharged to surface waters, except for combined sewer overflows:
(A) All POTWs with design flow rates greater than or equal to one million gallons per day;
(B) All POTWs with approved pretreatment programs or POTWs required to develop a pretreatment program;
(C) Other POTWs, as required by the Director, based on consideration of the following factors:
(1) The variability of the pollutants or pollutant parameters in the POTW effluent (based on chemical-specific information, the type of treatment plant, and types of industrial contributors);
(2) The ratio of effluent flow to receiving stream flow;
(3) Existing controls on point or non-point sources, including total maximum daily load calculations for the receiving stream segment and the relative contribution of the POTW;
(4) Receiving stream characteristics, including possible or known water quality impairment, and whether the POTW discharges to a coastal water, one of the Great Lakes, or a water designated as an outstanding natural resource water; or
(5) Other considerations (including, but not limited to, the history of toxic impacts and compliance problems at the POTW) that the Director determines could cause or contribute to adverse water quality impacts.
(iii) Where the POTW has two or more outfalls with substantially identical effluent discharging to the same receiving stream segment, the Director may allow applicants to submit whole effluent toxicity data for only one outfall on a case-by-case basis. The Director may also allow applicants to composite samples from one or more outfalls that discharge into the same mixing zone.
(iv) Each applicant required to perform whole effluent toxicity testing pursuant to paragraph (j)(5)(ii) of this section must provide:
(A) Results of a minimum of four quarterly tests for a year, from the year preceding the permit application; or
(B) Results from four tests performed at least annually in the four and one half year period prior to the application, provided the results show no appreciable toxicity using a safety factor determined by the permitting authority.
(v) Applicants must conduct tests with multiple species (no less than two species; e.g., fish, invertebrate, plant), and test for acute or chronic toxicity, depending on the range of receiving water dilution. EPA recommends that applicants conduct acute or chronic testing based on the following dilutions:
(A) Acute toxicity testing if the dilution of the effluent is greater than 1000:1 at the edge of the mixing zone;
(B) Acute or chronic toxicity testing if the dilution of the effluent is between 100:1 and 1000:1 at the edge of the mixing zone. Acute testing may be more appropriate at the higher end of this range (1000:1), and chronic testing may be more appropriate at the lower end of this range (100:1); and
(C) Chronic testing if the dilution of the effluent is less than 100:1 at the edge of the mixing zone.
(vi) Each applicant required to perform whole effluent toxicity testing pursuant to paragraph (j)(5)(ii) of this section must provide the number of chronic or acute whole effluent toxicity tests that have been conducted since the last permit reissuance.
(vii) Applicants must provide the results using the form provided by the Director, or test summaries if available and comprehensive, for each whole effluent toxicity test conducted pursuant to paragraph (j)(5)(ii) of this section for which such information has not been reported previously to the Director.
(viii) Whole effluent toxicity testing conducted pursuant to paragraph (j)(5)(ii) of this section must be conducted using methods approved under 40 CFR part 136. West coast facilities in Washington, Oregon, California, Alaska, Hawaii, and the Pacific Territories are exempted from 40 CFR part 136 chronic methods and must use alternative guidance as directed by the permitting authority.
(ix) For whole effluent toxicity data submitted to the Director within four and one-half years prior to the date of the application, applicants must provide the dates on which the data were submitted and a summary of the results.
(x) Each POTW required to perform whole effluent toxicity testing pursuant to paragraph (j)(5)(ii) of this section must provide any information on the cause of toxicity and written details of any toxicity reduction evaluation conducted, if any whole effluent toxicity test conducted within the past four and one-half years revealed toxicity.
(6) Industrial discharges. Applicants must submit the following information about industrial discharges to the POTW:
(i) Number of significant industrial users (SIUs) and non-significant categorical industrial users (NSCIUs), as defined at 40 CFR 403.3(v), including SIUs and NSCIUs that truck or haul waste, discharging to the POTW; and
(ii) POTWs with one or more SIUs shall provide the following information for each SIU, as defined at 40 CFR 403.3(v), that discharges to the POTW:
(A) Name and mailing address;
(B) Description of all industrial processes that affect or contribute to the SIU’s discharge;
(C) Principal products and raw materials of the SIU that affect or contribute to the SIU’s discharge;
(D) Average daily volume of wastewater discharged, indicating the amount attributable to process flow and non-process flow;
(E) Whether the SIU is subject to local limits;
(F) Whether the SIU is subject to categorical standards, and if so, under which category(ies) and subcategory(ies); and
(G) Whether any problems at the POTW (e.g., upsets, pass through, interference) have been attributed to the SIU in the past four and one-half years.
(iii) The information required in paragraphs (j)(6)(i) and (ii) of this section may be waived by the Director for POTWs with pretreatment programs if the applicant has submitted either of the following that contain information substantially identical to that required in paragraphs (j)(6)(i) and (ii) of this section.
(A) An annual report submitted within one year of the application; or
(B) A pretreatment program;
(7) Discharges from hazardous waste generators and from waste cleanup or remediation sites. POTWs receiving Resource Conservation and Recovery Act (RCRA), Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA), or RCRA Corrective Action wastes or wastes generated at another type of cleanup or remediation site must provide the following information:
(i) If the POTW receives, or has been notified that it will receive, by truck, rail, or dedicated pipe any wastes that are regulated as RCRA hazardous wastes pursuant to 40 CFR part 261, the applicant must report the following:
(A) The method by which the waste is received (i.e., whether by truck, rail, or dedicated pipe); and
(B) The hazardous waste number and amount received annually of each hazardous waste;
(ii) If the POTW receives, or has been notified that it will receive, wastewaters that originate from remedial activities, including those undertaken pursuant to CERCLA and sections 3004(u) or 3008(h) of RCRA, the applicant must report the following:
(A) The identity and description of the site(s) or facility(ies) at which the wastewater originates;
(B) The identities of the wastewater’s hazardous constituents, as listed in appendix VIII of part 261 of this chapter; if known; and
(C) The extent of treatment, if any, the wastewater receives or will receive before entering the POTW;
(iii) Applicants are exempt from the requirements of paragraph (j)(7)(ii) of this section if they receive no more than fifteen kilograms per month of hazardous wastes, unless the wastes are acute hazardous wastes as specified in 40 CFR 261.30(d) and 261.33(e).
(8) Combined sewer overflows. Each applicant with combined sewer systems must provide the following information:
(i) Combined sewer system information. The following information regarding the combined sewer system:
(A) System map. A map indicating the location of the following:
(1) All CSO discharge points;
(2) Sensitive use areas potentially affected by CSOs (e.g., beaches, drinking water supplies, shellfish beds, sensitive aquatic ecosystems, and outstanding national resource waters); and
(3) Waters supporting threatened and endangered species potentially affected by CSOs; and
(B) System diagram. A diagram of the combined sewer collection system that includes the following information:
(1) The location of major sewer trunk lines, both combined and separate sanitary;
(2) The locations of points where separate sanitary sewers feed into the combined sewer system;
(3) In-line and off-line storage structures;
(4) The locations of flow-regulating devices; and
(5) The locations of pump stations;
(ii) Information on CSO outfalls. The following information for each CSO discharge point covered by the permit application:
(A) Description of outfall. The following information on each outfall:
(1) Outfall number;
(2) State, county, and city or town in which outfall is located;
(3) Latitude and longitude, to the nearest second; and
(4) Distance from shore and depth below surface;
(5) Whether the applicant monitored any of the following in the past year for this CSO:
(i) Rainfall;
(ii) CSO flow volume;
(iii) CSO pollutant concentrations;
(iv) Receiving water quality;
(v) CSO frequency; and
(6) The number of storm events monitored in the past year;
(B) CSO events. The following information about CSO overflows from each outfall:
(1) The number of events in the past year;
(2) The average duration per event, if available;
(3) The average volume per CSO event, if available; and
(4) The minimum rainfall that caused a CSO event, if available, in the last year;
(C) Description of receiving waters. The following information about receiving waters:
(1) Name of receiving water;
(2) Name of watershed/stream system and the United States Soil Conservation Service watershed (14-digit) code (if known); and
(3) Name of State Management/River Basin and the United States Geological Survey hydrologic cataloging unit (8-digit) code (if known); and
(D) CSO operations. A description of any known water quality impacts on the receiving water caused by the CSO (e.g., permanent or intermittent beach closings, permanent or intermittent shellfish bed closings, fish kills, fish advisories, other recreational loss, or exceedance of any applicable State water quality standard);
(iii) Public notification plan for CSO discharges to the Great Lakes Basin. Each permittee authorized to discharge a combined sewer overflow to the Great Lakes Basin as defined in § 122.2 must submit a public notification plan developed in accordance with § 122.38 as part of its permit application. The public notification plan shall describe any significant updates to the plan that may have occurred since the last plan submission.
(9) Contractors. All applicants must provide the name, mailing address, telephone number, electronic mail address and responsibilities of all contractors responsible for any operational or maintenance aspects of the facility; and
(10) Signature. All applications must be signed by a certifying official in compliance with § 122.22.
(k) Application requirements for new sources and new discharges. New manufacturing, commercial, mining and silvicultural dischargers applying for NPDES permits (except for new discharges of facilities subject to the requirements of paragraph (h) of this section or new discharges of storm water associated with industrial activity which are subject to the requirements of § 122.26(c)(1) and this section (except as provided by § 122.26(c)(1)(ii)) shall provide the following information to the Director, using the application forms provided by the Director:
(1) Expected outfall location. The latitude and longitude to the nearest 15 seconds and the name of the receiving water.
(2) Discharge dates. The expected date of commencement of discharge.
(3) Flows, sources of pollution, and treatment technologies – (i) Expected treatment of wastewater. Description of the treatment that the wastewater will receive, along with all operations contributing wastewater to the effluent, average flow contributed by each operation, and the ultimate disposal of any solid or liquid wastes not discharged.
(ii) Line drawing. A line drawing of the water flow through the facility with a water balance as described in § 122.21(g)(2).
(iii) Intermittent flows. If any of the expected discharges will be intermittent or seasonal, a description of the frequency, duration and maximum daily flow rate of each discharge occurrence (except for stormwater runoff, spillage, or leaks).
(4) Production. If a new source performance standard promulgated under section 306 of CWA or an effluent limitation guideline applies to the applicant and is expressed in terms of production (or other measure of operation), a reasonable measure of the applicant’s expected actual production reported in the units used in the applicable effluent guideline or new source performance standard as required by § 122.45(b)(2) for each of the first three years. Alternative estimates may also be submitted if production is likely to vary.
(5) Effluent characteristics. The requirements in paragraphs (h)(4)(i), (ii), and (iii) of this section that an applicant must provide estimates of certain pollutants expected to be present do not apply to pollutants present in a discharge solely as a result of their presence in intake water; however, an applicant must report such pollutants as present. Net credits may be provided for the presence of pollutants in intake water if the requirements of § 122.45(g) are met. All levels (except for discharge flow, temperature, and pH) must be estimated as concentration and as total mass.
(i) Each applicant must report estimated daily maximum, daily average, and source of information for each outfall for the following pollutants or parameters. The Director may waive the reporting requirements for any of these pollutants and parameters if the applicant submits a request for such a waiver before or with his application which demonstrates that information adequate to support issuance of the permit can be obtained through less stringent reporting requirements.
(A) Biochemical Oxygen Demand (BOD).
(B) Chemical Oxygen Demand (COD).
(C) Total Organic Carbon (TOC).
(D) Total Suspended Solids (TSS).
(E) Flow.
(F) Ammonia (as N).
(G) Temperature (winter and summer).
(H) pH.
(ii) Each applicant must report estimated daily maximum, daily average, and source of information for each outfall for the following pollutants, if the applicant knows or has reason to believe they will be present or if they are limited by an effluent limitation guideline or new source performance standard either directly or indirectly through limitations on an indicator pollutant: all pollutants in table IV of appendix D of part 122 (certain conventional and nonconventional pollutants).
(iii) Each applicant must report estimated daily maximum, daily average and source of information for the following pollutants if he knows or has reason to believe that they will be present in the discharges from any outfall:
(A) The pollutants listed in table III of appendix D (the toxic metals, in the discharge from any outfall: Total cyanide, and total phenols);
(B) The organic toxic pollutants in table II of appendix D (except bis (chloromethyl) ether, dichlorofluoromethane and trichlorofluoromethane). This requirement is waived for applicants with expected gross sales of less than $100,000 per year for the next three years, and for coal mines with expected average production of less than 100,000 tons of coal per year.
(iv) The applicant is required to report that 2,3,7,8 Tetrachlorodibenzo-P-Dioxin (TCDD) may be discharged if he uses or manufactures one of the following compounds, or if he knows or has reason to believe that TCDD will or may be present in an effluent:
(A) 2,4,5-trichlorophenoxy acetic acid (2,4,5-T) (CAS #93-76-5);
(B) 2-(2,4,5-trichlorophenoxy) propanoic acid (Silvex, 2,4,5-TP) (CAS #93-72-1);
(C) 2-(2,4,5-trichlorophenoxy) ethyl 2,2-dichloropropionate (Erbon) (CAS #136-25-4);
(D) 0,0-dimethyl 0-(2,4,5-trichlorophenyl) phosphorothioate (Ronnel) (CAS #299-84-3);
(E) 2,4,5-trichlorophenol (TCP) (CAS #95-95-4); or
(F) Hexachlorophene (HCP) (CAS #70-30-4);
(v) Each applicant must report any pollutants listed in table V of appendix D (certain hazardous substances) if he believes they will be present in any outfall (no quantitative estimates are required unless they are already available).
(vi) No later than 24 months after the commencement of discharge from the proposed facility, the applicant is required to complete and submit items V and VI of NPDES application Form 2C (see § 122.21(g)). However, the applicant need not complete those portions of Item V requiring tests which have already been performed and reported under the discharge monitoring requirements of the NPDES permit.
(6) Engineering Report. Each applicant must report the existence of any technical evaluation concerning his wastewater treatment, along with the name and location of similar plants of which he has knowledge.
(7) Other information. Any optional information the permittee wishes to have considered.
(8) Certification. Signature of certifying official under § 122.22.
(l) Special provisions for applications from new sources. (1) The owner or operator of any facility which may be a new source (as defined in § 122.2) and which is located in a State without an approved NPDES program must comply with the provisions of this paragraph (l)(1).
(2)(i) Before beginning any on-site construction as defined in § 122.29, the owner or operator of any facility which may be a new source must submit information to the Regional Administrator so that he or she can determine if the facility is a new source. The Regional Administrator may request any additional information needed to determine whether the facility is a new source.
(ii) The Regional Administrator shall make an initial determination whether the facility is a new source within 30 days of receiving all necessary information under paragraph (l)(2)(i) of this section.
(3) The Regional Administrator shall issue a public notice in accordance with § 124.10 of this chapter of the new source determination under paragraph (l)(2) of this section. If the Regional Administrator has determined that the facility is a new source, the notice shall state that the applicant must comply with the environmental review requirements of 40 CFR 6.600 through 6.607.
(4) Any interested party may challenge the Regional Administrator’s initial new source determination by requesting review of the determination under § 124.19 of this chapter within 30 days of the public notice of the initial determination. If all interested parties agree, the Environmental Appeals Board may defer review until after a final permit decision is made, and consolidate review of the determination with any review of the permit decision.
(m) Variance requests by non-POTWs. A discharger which is not a publicly owned treatment works (POTW) may request a variance from otherwise applicable effluent limitations under any of the following statutory or regulatory provisions within the times specified in this paragraph:
(1) Fundamentally different factors. (i) A request for a variance based on the presence of “fundamentally different factors” from those on which the effluent limitations guideline was based shall be filed as follows:
(A) For a request from best practicable control technology currently available (BPT), by the close of the public comment period under § 124.10.
(B) For a request from best available technology economically achievable (BAT) and/or best conventional pollutant control technology (BCT), by no later than:
(1) July 3, 1989, for a request based on an effluent limitation guideline promulgated before February 4, 1987, to the extent July 3, 1989 is not later than that provided under previously promulgated regulations; or
(2) 180 days after the date on which an effluent limitation guideline is published in the
(ii) The request shall explain how the requirements of the applicable regulatory and/or statutory criteria have been met.
(2) Non-conventional pollutants. A request for a variance from the BAT requirements for CWA section 301(b)(2)(F) pollutants (commonly called “non-conventional” pollutants) pursuant to section 301(c) of CWA because of the economic capability of the owner or operator, or pursuant to section 301(g) of the CWA (provided however that a § 301(g) variance may only be requested for ammonia; chlorine; color; iron; total phenols (4AAP) (when determined by the Administrator to be a pollutant covered by section 301(b)(2)(F)) and any other pollutant which the Administrator lists under section 301(g)(4) of the CWA) must be made as follows:
(i) For those requests for a variance from an effluent limitation based upon an effluent limitation guideline by:
(A) Submitting an initial request to the Regional Administrator, as well as to the State Director if applicable, stating the name of the discharger, the permit number, the outfall number(s), the applicable effluent guideline, and whether the discharger is requesting a section 301(c) or section 301(g) modification or both. This request must have been filed not later than:
(1) September 25, 1978, for a pollutant which is controlled by a BAT effluent limitation guideline promulgated before December 27, 1977; or
(2) 270 days after promulgation of an applicable effluent limitation guideline for guidelines promulgated after December 27, 1977; and
(B) Submitting a completed request no later than the close of the public comment period under § 124.10 demonstrating that the requirements of § 124.13 and the applicable requirements of part 125 have been met. Notwithstanding this provision, the complete application for a request under section 301(g) shall be filed 180 days before EPA must make a decision (unless the Regional Division Director establishes a shorter or longer period).
(ii) For those requests for a variance from effluent limitations not based on effluent limitation guidelines, the request need only comply with paragraph (m)(2)(i)(B) of this section and need not be preceded by an initial request under paragraph (m)(2)(i)(A) of this section.
(3)-(4) [Reserved]
(5) Water quality related effluent limitations. A modification under section 302(b)(2) of requirements under section 302(a) for achieving water quality related effluent limitations may be requested no later than the close of the public comment period under § 124.10 on the permit from which the modification is sought.
(6) Thermal discharges. A variance under CWA section 316(a) for the thermal component of any discharge must be filed with a timely application for a permit under this section, except that if thermal effluent limitations are established under CWA section 402(a)(1) or are based on water quality standards the request for a variance may be filed by the close of the public comment period under § 124.10. A copy of the request as required under 40 CFR part 125, subpart H, shall be sent simultaneously to the appropriate State or interstate certifying agency as required under 40 CFR part 125. (See § 124.65 for special procedures for section 316(a) thermal variances.)
(n) Variance requests by POTWs. A discharger which is a publicly owned treatment works (POTW) may request a variance from otherwise applicable effluent limitations under any of the following statutory provisions as specified in this paragraph:
(1) Discharges into marine waters. A request for a modification under CWA section 301(h) of requirements of CWA section 301(b)(1)(B) for discharges into marine waters must be filed in accordance with the requirements of 40 CFR part 125, subpart G.
(2) [Reserved]
(3) Water quality based effluent limitation. A modification under CWA section 302(b)(2) of the requirements under section 302(a) for achieving water quality based effluent limitations shall be requested no later than the close of the public comment period under § 124.10 on the permit from which the modification is sought.
(o) Expedited variance procedures and time extensions. (1) Notwithstanding the time requirements in paragraphs (m) and (n) of this section, the Director may notify a permit applicant before a draft permit is issued under § 124.6 that the draft permit will likely contain limitations which are eligible for variances. In the notice the Director may require the applicant as a condition of consideration of any potential variance request to submit a request explaining how the requirements of part 125 applicable to the variance have been met and may require its submission within a specified reasonable time after receipt of the notice. The notice may be sent before the permit application has been submitted. The draft or final permit may contain the alternative limitations which may become effective upon final grant of the variance.
(2) A discharger who cannot file a timely complete request required under paragraph (m)(2)(i)(B) or (m)(2)(ii) of this section may request an extension. The extension may be granted or denied at the discretion of the Director. Extensions shall be no more than 6 months in duration.
(p) Recordkeeping. Except for information required by paragraph (d)(3)(ii) of this section, which shall be retained for a period of at least five years from the date the application is signed (or longer as required by 40 CFR part 503), applicants shall keep records of all data used to complete permit applications and any supplemental information submitted under this section for a period of at least 3 years from the date the application is signed.
(q) Sewage sludge management. All TWTDS subject to paragraph (c)(2)(i) of this section must provide the information in this paragraph to the Director, using Form 2S or another application form approved by the Director. New applicants must submit all information available at the time of permit application. The information may be provided by referencing information previously submitted to the Director. The Director may waive any requirement of this paragraph if he or she has access to substantially identical information. The Director may also waive any requirement of this paragraph that is not of material concern for a specific permit, if approved by the Regional Administrator. The waiver request to the Regional Administrator must include the State’s justification for the waiver. A Regional Administrator’s disapproval of a State’s proposed waiver does not constitute final Agency action, but does provide notice to the State and permit applicant(s) that EPA may object to any State-issued permit issued in the absence of the required information.
(1) Facility information. All applicants must submit the following information:
(i) The name, mailing address, and location of the TWTDS for which the application is submitted;
(ii) Whether the facility is a Class I Sludge Management Facility;
(iii) The design flow rate (in million gallons per day);
(iv) The total population served; and
(v) The TWTDS’s status as Federal, State, private, public, or other entity;
(2) Applicant information. All applicants must submit the following information:
(i) The name, mailing address, telephone number, and electronic mail address of the applicant; and
(ii) Indication whether the applicant is the owner, operator, or both;
(3) Permit information. All applicants must submit the facility’s NPDES permit number, if applicable, and a listing of all other Federal, State, and local permits or construction approvals received or applied for under any of the following programs:
(i) Hazardous Waste Management program under the Resource Conservation and Recovery Act (RCRA);
(ii) UIC program under the Safe Drinking Water Act (SDWA);
(iii) NPDES program under the Clean Water Act (CWA);
(iv) Prevention of Significant Deterioration (PSD) program under the Clean Air Act;
(v) Nonattainment program under the Clean Air Act;
(vi) National Emission Standards for Hazardous Air Pollutants (NESHAPS) preconstruction approval under the Clean Air Act;
(vii) Dredge or fill permits under section 404 of CWA;
(viii) Other relevant environmental permits, including State or local permits;
(4) Indian country. All applicants must identify any generation, treatment, storage, land application, or disposal of sewage sludge that occurs in Indian country;
(5) Topographic map. All applicants must submit a topographic map (or other map if a topographic map is unavailable) extending one mile beyond property boundaries of the facility and showing the following information:
(i) All sewage sludge management facilities, including on-site treatment, storage, and disposal sites; and
(ii) Wells, springs, and other surface water bodies that are within
(6) Sewage sludge handling. All applicants must submit a line drawing and/or a narrative description that identifies all sewage sludge management practices employed during the term of the permit, including all units used for collecting, dewatering, storing, or treating sewage sludge, the destination(s) of all liquids and solids leaving each such unit, and all processes used for pathogen reduction and vector attraction reduction;
(7) Sewage sludge quality. The applicant must submit sewage sludge monitoring data for the pollutants for which limits in sewage sludge have been established in 40 CFR part 503 for the applicant’s use or disposal practices on the date of permit application.
(i) The Director may require sampling for additional pollutants, as appropriate, on a case-by-case basis;
(ii) Applicants must provide data from a minimum of three samples taken within four and one-half years prior to the date of the permit application. Samples must be representative of the sewage sludge and should be taken at least one month apart. Existing data may be used in lieu of sampling done solely for the purpose of this application;
(iii) Applicants must collect and analyze samples in accordance with analytical methods approved under SW-846 unless an alternative has been specified in an existing sewage sludge permit;
(iv) The monitoring data provided must include at least the following information for each parameter:
(A) Average monthly concentration for all samples (mg/kg dry weight), based upon actual sample values;
(B) The analytical method used; and
(C) The method detection level.
(8) Preparation of sewage sludge. If the applicant is a “person who prepares” sewage sludge, as defined at 40 CFR 503.9(r), the applicant must provide the following information:
(i) If the applicant’s facility generates sewage sludge, the total dry metric tons per 365-day period generated at the facility;
(ii) If the applicant’s facility receives sewage sludge from another facility, the following information for each facility from which sewage sludge is received:
(A) The name, mailing address, and location of the other facility;
(B) The total dry metric tons per 365-day period received from the other facility; and
(C) A description of any treatment processes occurring at the other facility, including blending activities and treatment to reduce pathogens or vector attraction characteristics;
(iii) If the applicant’s facility changes the quality of sewage sludge through blending, treatment, or other activities, the following information:
(A) Whether the Class A pathogen reduction requirements in 40 CFR 503.32(a) or the Class B pathogen reduction requirements in 40 CFR 503.32(b) are met, and a description of any treatment processes used to reduce pathogens in sewage sludge;
(B) Whether any of the vector attraction reduction options of 40 CFR 503.33(b)(1) through (b)(8) are met, and a description of any treatment processes used to reduce vector attraction properties in sewage sludge; and
(C) A description of any other blending, treatment, or other activities that change the quality of sewage sludge;
(iv) If sewage sludge from the applicant’s facility meets the ceiling concentrations in 40 CFR 503.13(b)(1), the pollutant concentrations in § 503.13(b)(3), the Class A pathogen requirements in § 503.32(a), and one of the vector attraction reduction requirements in § 503.33(b)(1) through (b)(8), and if the sewage sludge is applied to the land, the applicant must provide the total dry metric tons per 365-day period of sewage sludge subject to this paragraph that is applied to the land;
(v) If sewage sludge from the applicant’s facility is sold or given away in a bag or other container for application to the land, and the sewage sludge is not subject to paragraph (q)(8)(iv) of this section, the applicant must provide the following information:
(A) The total dry metric tons per 365-day period of sewage sludge subject to this paragraph that is sold or given away in a bag or other container for application to the land; and
(B) A copy of all labels or notices that accompany the sewage sludge being sold or given away;
(vi) If sewage sludge from the applicant’s facility is provided to another “person who prepares,” as defined at 40 CFR 503.9(r), and the sewage sludge is not subject to paragraph (q)(8)(iv) of this section, the applicant must provide the following information for each facility receiving the sewage sludge:
(A) The name, mailing address, and electronic mail address of the receiving facility;
(B) The total dry metric tons per 365-day period of sewage sludge subject to this paragraph that the applicant provides to the receiving facility;
(C) A description of any treatment processes occurring at the receiving facility, including blending activities and treatment to reduce pathogens or vector attraction characteristic;
(D) A copy of the notice and necessary information that the applicant is required to provide the receiving facility under 40 CFR 503.12(g); and
(E) If the receiving facility places sewage sludge in bags or containers for sale or give-away to application to the land, a copy of any labels or notices that accompany the sewage sludge;
(9) Land application of bulk sewage sludge. If sewage sludge from the applicant’s facility is applied to the land in bulk form, and is not subject to paragraphs (q)(8)(iv), (v), or (vi) of this section, the applicant must provide the following information:
(i) The total dry metric tons per 365-day period of sewage sludge subject to this paragraph that is applied to the land;
(ii) If any land application sites are located in States other than the State where the sewage sludge is prepared, a description of how the applicant will notify the permitting authority for the State(s) where the land application sites are located;
(iii) The following information for each land application site that has been identified at the time of permit application:
(A) The name (if any), and location for the land application site;
(B) The site’s latitude and longitude to the nearest second, and method of determination;
(C) A topographic map (or other map if a topographic map is unavailable) that shows the site’s location;
(D) The name, mailing address, telephone number, and electronic mail address of the site owner, if different from the applicant;
(E) The name, mailing address, telephone number, and electronic mail address of the person who applies sewage sludge to the site, if different from the applicant;
(F) Whether the site is agricultural land, forest, a public contact site, or a reclamation site, as such site types are defined under 40 CFR 503.11;
(G) The type of vegetation grown on the site, if known, and the nitrogen requirement for this vegetation;
(H) Whether either of the vector attraction reduction options of 40 CFR 503.33(b)(9) or (b)(10) is met at the site, and a description of any procedures employed at the time of use to reduce vector attraction properties in sewage sludge; and
(I) Other information that describes how the site will be managed, as specified by the permitting authority.
(iv) The following information for each land application site that has been identified at the time of permit application, if the applicant intends to apply bulk sewage sludge subject to the cumulative pollutant loading rates in 40 CFR 503.13(b)(2) to the site:
(A) Whether the applicant has contacted the permitting authority in the State where the bulk sewage sludge subject to § 503.13(b)(2) will be applied, to ascertain whether bulk sewage sludge subject to § 503.13(b)(2) has been applied to the site on or since July 20, 1993, and if so, the name of the permitting authority and the name, phone number, and electronic mail address if available, of a contact person at the permitting authority;
(B) Identification of facilities other than the applicant’s facility that have sent, or are sending, sewage sludge subject to the cumulative pollutant loading rates in § 503.13(b)(2) to the site since July 20, 1993, if, based on the inquiry in paragraph (q)(iv)(A), bulk sewage sludge subject to cumulative pollutant loading rates in § 503.13(b)(2) has been applied to the site since July 20, 1993;
(v) If not all land application sites have been identified at the time of permit application, the applicant must submit a land application plan that, at a minimum:
(A) Describes the geographical area covered by the plan;
(B) Identifies the site selection criteria;
(C) Describes how the site(s) will be managed;
(D) Provides for advance notice to the permit authority of specific land application sites and reasonable time for the permit authority to object prior to land application of the sewage sludge; and
(E) Provides for advance public notice of land application sites in the manner prescribed by State and local law. When State or local law does not require advance public notice, it must be provided in a manner reasonably calculated to apprize the general public of the planned land application.
(10) Surface disposal. If sewage sludge from the applicant’s facility is placed on a surface disposal site, the applicant must provide the following information:
(i) The total dry metric tons of sewage sludge from the applicant’s facility that is placed on surface disposal sites per 365-day period;
(ii) The following information for each surface disposal site receiving sewage sludge from the applicant’s facility that the applicant does not own or operate:
(A) The site name or number, contact person, mailing address, telephone number, and electronic mail address for the surface disposal site; and
(B) The total dry metric tons from the applicant’s facility per 365-day period placed on the surface disposal site;
(iii) The following information for each active sewage sludge unit at each surface disposal site that the applicant owns or operates:
(A) The name or number and the location of the active sewage sludge unit;
(B) The unit’s latitude and longitude to the nearest second, and method of determination;
(C) If not already provided, a topographic map (or other map if a topographic map is unavailable) that shows the unit’s location;
(D) The total dry metric tons placed on the active sewage sludge unit per 365-day period;
(E) The total dry metric tons placed on the active sewage sludge unit over the life of the unit;
(F) A description of any liner for the active sewage sludge unit, including whether it has a maximum permeability of 1 × 10
(G) A description of any leachate collection system for the active sewage sludge unit, including the method used for leachate disposal, and any Federal, State, and local permit number(s) for leachate disposal;
(H) If the active sewage sludge unit is less than 150 meters from the property line of the surface disposal site, the actual distance from the unit boundary to the site property line;
(I) The remaining capacity (dry metric tons) for the active sewage sludge unit;
(J) The date on which the active sewage sludge unit is expected to close, if such a date has been identified;
(K) The following information for any other facility that sends sewage sludge to the active sewage sludge unit:
(1) The name, contact person, mailing address, and electronic mail address of the facility; and
(2) Available information regarding the quality of the sewage sludge received from the facility, including any treatment at the facility to reduce pathogens or vector attraction characteristics;
(L) Whether any of the vector attraction reduction options of 40 CFR 503.33(b)(9) through (b)(11) is met at the active sewage sludge unit, and a description of any procedures employed at the time of disposal to reduce vector attraction properties in sewage sludge;
(M) The following information, as applicable to any ground-water monitoring occurring at the active sewage sludge unit:
(1) A description of any ground-water monitoring occurring at the active sewage sludge unit;
(2) Any available ground-water monitoring data, with a description of the well locations and approximate depth to ground water;
(3) A copy of any ground-water monitoring plan that has been prepared for the active sewage sludge unit;
(4) A copy of any certification that has been obtained from a qualified ground-water scientist that the aquifer has not been contaminated; and
(N) If site-specific pollutant limits are being sought for the sewage sludge placed on this active sewage sludge unit, information to support such a request;
(11) Incineration. If sewage sludge from the applicant’s facility is fired in a sewage sludge incinerator, the applicant must provide the following information:
(i) The total dry metric tons of sewage sludge from the applicant’s facility that is fired in sewage sludge incinerators per 365-day period;
(ii) The following information for each sewage sludge incinerator firing the applicant’s sewage sludge that the applicant does not own or operate:
(A) The name and/or number, contact person, mailing address, telephone number, and electronic mail address of the sewage sludge incinerator; and
(B) The total dry metric tons from the applicant’s facility per 365-day period fired in the sewage sludge incinerator;
(iii) The following information for each sewage sludge incinerator that the applicant owns or operates:
(A) The name and/or number and the location of the sewage sludge incinerator;
(B) The incinerator’s latitude and longitude to the nearest second, and method of determination;
(C) The total dry metric tons per 365-day period fired in the sewage sludge incinerator;
(D) Information, test data, and documentation of ongoing operating parameters indicating that compliance with the National Emission Standard for Beryllium in 40 CFR part 61 will be achieved;
(E) Information, test data, and documentation of ongoing operating parameters indicating that compliance with the National Emission Standard for Mercury in 40 CFR part 61 will be achieved;
(F) The dispersion factor for the sewage sludge incinerator, as well as modeling results and supporting documentation;
(G) The control efficiency for parameters regulated in 40 CFR 503.43, as well as performance test results and supporting documentation;
(H) Information used to calculate the risk specific concentration (RSC) for chromium, including the results of incinerator stack tests for hexavalent and total chromium concentrations, if the applicant is requesting a chromium limit based on a site-specific RSC value;
(I) Whether the applicant monitors total hydrocarbons (THC) or Carbon Monoxide (CO) in the exit gas for the sewage sludge incinerator;
(J) The type of sewage sludge incinerator;
(K) The maximum performance test combustion temperature, as obtained during the performance test of the sewage sludge incinerator to determine pollutant control efficiencies;
(L) The following information on the sewage sludge feed rate used during the performance test:
(1) Sewage sludge feed rate in dry metric tons per day;
(2) Identification of whether the feed rate submitted is average use or maximum design; and
(3) A description of how the feed rate was calculated;
(M) The incinerator stack height in meters for each stack, including identification of whether actual or creditable stack height was used;
(N) The operating parameters for the sewage sludge incinerator air pollution control device(s), as obtained during the performance test of the sewage sludge incinerator to determine pollutant control efficiencies;
(O) Identification of the monitoring equipment in place, including (but not limited to) equipment to monitor the following:
(1) Total hydrocarbons or Carbon Monoxide;
(2) Percent oxygen;
(3) Percent moisture; and
(4) Combustion temperature; and
(P) A list of all air pollution control equipment used with this sewage sludge incinerator;
(12) Disposal in a municipal solid waste landfill. If sewage sludge from the applicant’s facility is sent to a municipal solid waste landfill (MSWLF), the applicant must provide the following information for each MSWLF to which sewage sludge is sent:
(i) The name, contact person, mailing address, electronic mail address, location, and all applicable permit numbers of the MSWLF;
(ii) The total dry metric tons per 365-day period sent from this facility to the MSWLF;
(iii) A determination of whether the sewage sludge meets applicable requirements for disposal of sewage sludge in a MSWLF, including the results of the paint filter liquids test and any additional requirements that apply on a site-specific basis; and
(iv) Information, if known, indicating whether the MSWLF complies with criteria set forth in 40 CFR part 258;
(13) Contractors. All applicants must provide the name, mailing address, telephone number, electronic mail address and responsibilities of all contractors responsible for any operational or maintenance aspects of the facility related to sewage sludge generation, treatment, use, or disposal;
(14) Other information. At the request of the permitting authority, the applicant must provide any other information necessary to determine the appropriate standards for permitting under 40 CFR part 503, and must provide any other information necessary to assess the sewage sludge use and disposal practices, determine whether to issue a permit, or identify appropriate permit requirements; and
(15) Signature. All applications must be signed by a certifying official in compliance with § 122.22.
[Note 1: At 46 FR 2046, Jan. 8, 1981, the Environmental Protection Agency suspended until further notice § 122.21(g)(7)(v)(A) and the corresponding portions of Item V-C of the NPDES application Form 2C as they apply to coal mines. This suspension continues in effect.]
[Note 2: At 46 FR 22585, Apr. 20, 1981, the Environmental Protection Agency suspended until further notice § 122.21(g)(7)(v)(A) and the corresponding portions of Item V-C of the NPDES application Form 2C as they apply to:
a. Testing and reporting for all four organic fractions in the Greige Mills Subcategory of the Textile Mills industry (subpart C – Low water use processing of 40 CFR part 410), and testing and reporting for the pesticide fraction in all other subcategories of this industrial category.
b. Testing and reporting for the volatile, base/neutral and pesticide fractions in the Base and Precious Metals Subcategory of the Ore Mining and Dressing industry (subpart B of 40 CFR part 440), and testing and reporting for all four fractions in all other subcategories of this industrial category.
c. Testing and reporting for all four GC/MS fractions in the Porcelain Enameling industry.
[Note 3: At 46 FR 35090, July 1, 1981, the Environmental Protection Agency suspended until further notice § 122.21(g)(7)(v)(A) and the corresponding portions of Item V-C of the NPDES application Form 2C as they apply to:
a. Testing and reporting for the pesticide fraction in the Tall Oil Rosin Subcategory (subpart D) and Rosin-Based Derivatives Subcategory (subpart F) of the Gum and Wood Chemicals industry (40 CFR part 454), and testing and reporting for the pesticide and base-neutral fractions in all other subcategories of this industrial category.
b. Testing and reporting for the pesticide fraction in the Leather Tanning and Finishing, Paint and Ink Formulation, and Photographic Supplies industrial categories.
c. Testing and reporting for the acid, base/neutral and pesticide fractions in the Petroleum Refining industrial category.
d. Testing and reporting for the pesticide fraction in the Papergrade Sulfite subcategories (subparts J and U) of the Pulp and Paper industry (40 CFR part 430); testing and reporting for the base/neutral and pesticide fractions in the following subcategories: Deink (subpart Q), Dissolving Kraft (subpart F), and Paperboard from Waste Paper (subpart E); testing and reporting for the volatile, base/neutral and pesticide fractions in the following subcategories: BCT Bleached Kraft (subpart H), Semi-Chemical (subparts B and C), and Nonintegrated-Fine Papers (subpart R); and testing and reporting for the acid, base/neutral, and pesticide fractions in the following subcategories: Fine Bleached Kraft (subpart I), Dissolving Sulfite Pulp (subpart K), Groundwood-Fine Papers (subpart O), Market Bleached Kraft (subpart G), Tissue from Wastepaper (subpart T), and Nonintegrated-Tissue Papers (subpart S).
e. Testing and reporting for the base/neutral fraction in the Once-Through Cooling Water, Fly Ash and Bottom Ash Transport Water process wastestreams of the Steam Electric Power Plant industrial category.
(r) Application requirements for facilities with cooling water intake structures –
(1)(i) New facilities with new or modified cooling water intake structures. New facilities (other than offshore oil and gas extraction facilities) with cooling water intake structures as defined in part 125, subpart I of this chapter, must submit to the Director for review the information required under paragraphs (r)(2) (except (r)(2)(iv)), (3), and (4) (except (r)(4)(ix), (x), (xi), and (xii)) of this section and § 125.86 of this chapter as part of the permit application. New offshore oil and gas extraction facilities with cooling water intake structures as defined in part 125, subpart N, of this chapter that are fixed facilities must submit to the Director for review the information required under paragraphs (r)(2) (except (r)(2)(iv)), (3), and (4) (except (r)(4)(ix), (x), (xi), and (xii)) of this section and § 125.136 of this chapter as part of their permit application.
(ii) Existing facilities. (A) All existing facilities. The owner or operator of an existing facility defined at 40 CFR 125.92(k) must submit to the Director for review the information required under paragraphs (r)(2) and (3) of this section and applicable provisions of paragraphs (r)(4), (5), (6), (7), and (8) of this section.
(B) Existing facilities greater than 125 mgd AIF. In addition, the owner or operator of an existing facility that withdraws greater than 125 mgd actual intake flow (AIF), as defined at 40 CFR 125.92 (a), of water for cooling purposes must also submit to the Director for review the information required under paragraphs (r)(9), (10), (11), (12), and (13) of this section. If the owner or operator of an existing facility intends to comply with the BTA (best technology available) standards for entrainment using a closed-cycle recirculating system as defined at 40 CFR 125.92(c), the Director may reduce or waive some or all of the information required under paragraphs (r)(9) through (13) of this section.
(C) Additional information. The owner or operator of an existing facility must also submit such additional information as the Director determines is necessary pursuant to 40 CFR 125.98(i).
(D) New units at existing facilities. The owner or operator of a new unit at an existing facility, as defined at 40 CFR 125.92(u), must submit or update any information previously provided to the Director by submitting the information required under paragraphs (r)(2), (3), (5), (8), and (14) of this section and applicable provisions of paragraphs (r)(4), (6), and (7) of this section. Requests for and approvals of alternative requirements sought under 40 CFR 125.94(e)(2) or 125.98(b)(7) must be submitted with the permit application.
(E) New units at existing facilities not previously subject to Part 125. The owner or operator of a new unit as defined at 40 CFR 125.92(u) at an existing facility not previously subject to part 125 of this chapter that increases the total capacity of the existing facility to more than 2 mgd DIF must submit the information required under paragraphs (r)(2), (3), (5), and (8) of this section and applicable provisions of paragraphs (r)(4), (6), and (7) of this section at the time of the permit application for the new unit. Requests for alternative requirements under 40 CFR 125.94(e)(2) or 125.98(b)(7) must be submitted with the permit application. If the total capacity of the facility will increase to more than 125 mgd AIF, the owner or operator must also submit the information required in paragraphs (r)(9) through (13) of this section. If the owner or operator of an existing facility intends to comply with the BTA (best technology available) standards for entrainment using a closed-cycle recirculating system as defined at 40 CFR 125.92(c), the Director may reduce or waive some or all of the information required under paragraphs (r)(9) through (13) of this section.
(F) If the owner or operator of an existing facility plans to retire the facility before the current permit expires, then the requirements of paragraphs (r)(1)(ii)(A), (B), (C), (D), and (E) of this section do not apply.
(G) If the owner or operator of an existing facility plans to retire the facility after the current permit expires but within one permit cycle, then the Director may waive the requirements of paragraphs (r)(7), (9), (10), (11), (12), and (13) of this section pending a signed certification statement from the owner or operator of the facility specifying the last operating date of the facility.
(H) All facilities. The owner or operator of any existing facility or new unit at any existing facility must also submit with its permit application all information received as a result of any communication with a Field Office of the Fish and Wildlife Service and/or Regional Office of the National Marine Fisheries Service.
(2) Source water physical data. These include:
(i) A narrative description and scaled drawings showing the physical configuration of all source water bodies used by your facility, including areal dimensions, depths, salinity and temperature regimes, and other documentation that supports your determination of the water body type where each cooling water intake structure is located;
(ii) Identification and characterization of the source waterbody’s hydrological and geomorphological features, as well as the methods you used to conduct any physical studies to determine your intake’s area of influence within the waterbody and the results of such studies;
(iii) Locational maps; and
(iv) For new offshore oil and gas facilities that are not fixed facilities, a narrative description and/or locational maps providing information on predicted locations within the waterbody during the permit term in sufficient detail for the Director to determine the appropriateness of additional impingement requirements under § 125.134(b)(4).
(3) Cooling water intake structure data. These include:
(i) A narrative description of the configuration of each of your cooling water intake structures and where it is located in the water body and in the water column;
(ii) Latitude and longitude in degrees, minutes, and seconds for each of your cooling water intake structures;
(iii) A narrative description of the operation of each of your cooling water intake structures, including design intake flows, daily hours of operation, number of days of the year in operation and seasonal changes, if applicable;
(iv) A flow distribution and water balance diagram that includes all sources of water to the facility, recirculating flows, and discharges; and
(v) Engineering drawings of the cooling water intake structure.
(4) Source water baseline biological characterization data. This information is required to characterize the biological community in the vicinity of the cooling water intake structure and to characterize the operation of the cooling water intake structures. The Director may also use this information in subsequent permit renewal proceedings to determine if your Design and Construction Technology Plan as required in § 125.86(b)(4) or § 125.136(b)(3) of this chapter should be revised. This supporting information must include existing data (if they are available). However, you may supplement the data using newly conducted field studies if you choose to do so. The information you submit must include:
(i) A list of the data in paragraphs (r)(4)(ii) through (vi) of this section that are not available and efforts made to identify sources of the data;
(ii) A list of species (or relevant taxa) for all life stages and their relative abundance in the vicinity of the cooling water intake structure;
(iii) Identification of the species and life stages that would be most susceptible to impingement and entrainment. Species evaluated should include the forage base as well as those most important in terms of significance to commercial and recreational fisheries;
(iv) Identification and evaluation of the primary period of reproduction, larval recruitment, and period of peak abundance for relevant taxa;
(v) Data representative of the seasonal and daily activities (e.g., feeding and water column migration) of biological organisms in the vicinity of the cooling water intake structure;
(vi) Identification of all threatened, endangered, and other protected species that might be susceptible to impingement and entrainment at your cooling water intake structures;
(vii) Documentation of any public participation or consultation with Federal or State agencies undertaken in development of the plan; and
(viii) If you supplement the information requested in paragraph (r)(4)(i) of this section with data collected using field studies, supporting documentation for the Source Water Baseline Biological Characterization must include a description of all methods and quality assurance procedures for sampling, and data analysis including a description of the study area; taxonomic identification of sampled and evaluated biological assemblages (including all life stages of fish and shellfish); and sampling and data analysis methods. The sampling and/or data analysis methods you use must be appropriate for a quantitative survey and based on consideration of methods used in other biological studies performed within the same source water body. The study area should include, at a minimum, the area of influence of the cooling water intake structure.
(ix) In the case of the owner or operator of an existing facility or new unit at an existing facility, the Source Water Baseline Biological Characterization Data is the information in paragraphs (r)(4)(i) through (xii) of this section.
(x) For the owner or operator of an existing facility, identification of protective measures and stabilization activities that have been implemented, and a description of how these measures and activities affected the baseline water condition in the vicinity of the intake.
(xi) For the owner or operator of an existing facility, a list of fragile species, as defined at 40 CFR 125.92(m), at the facility. The applicant need only identify those species not already identified as fragile at 40 CFR 125.92(m). New units at an existing facility are not required to resubmit this information if the cooling water withdrawals for the operation of the new unit are from an existing intake.
(xii) For the owner or operator of an existing facility that has obtained incidental take exemption or authorization for its cooling water intake structure(s) from the U.S. Fish and Wildlife Service or the National Marine Fisheries Service, any information submitted in order to obtain that exemption or authorization may be used to satisfy the permit application information requirement of paragraph 40 CFR 125.95(f) if included in the application.
(5) Cooling Water System Data. The owner or operator of an existing facility must submit the following information for each cooling water intake structure used or intended to be used:
(i) A narrative description of the operation of the cooling water system and its relationship to cooling water intake structures; the proportion of the design intake flow that is used in the system; the number of days of the year the cooling water system is in operation and seasonal changes in the operation of the system, if applicable; the proportion of design intake flow for contact cooling, non-contact cooling, and process uses; a distribution of water reuse to include cooling water reused as process water, process water reused for cooling, and the use of gray water for cooling; a description of reductions in total water withdrawals including cooling water intake flow reductions already achieved through minimized process water withdrawals; a description of any cooling water that is used in a manufacturing process either before or after it is used for cooling, including other recycled process water flows; the proportion of the source waterbody withdrawn (on a monthly basis);
(ii) Design and engineering calculations prepared by a qualified professional and supporting data to support the description required by paragraph (r)(5)(i) of this section; and
(iii) Description of existing impingement and entrainment technologies or operational measures and a summary of their performance, including but not limited to reductions in impingement mortality and entrainment due to intake location and reductions in total water withdrawals and usage.
(6) Chosen Method(s) of Compliance with Impingement Mortality Standard. The owner or operator of the facility must identify the chosen compliance method for the entire facility; alternatively, the applicant must identify the chosen compliance method for each cooling water intake structure at its facility. The applicant must identify any intake structure for which a BTA determination for Impingement Mortality under 40 CFR 125.94 (c)(11) or (12) is requested. In addition, the owner or operator that chooses to comply via 40 CFR 125.94 (c)(5) or (6) must also submit an impingement technology performance optimization study as described below:
(i) If the applicant chooses to comply with 40 CFR 125.94(c)(5), subject to the flexibility for timing provided in 40 CFR 125.95(a)(2), the impingement technology performance optimization study must include two years of biological data collection measuring the reduction in impingement mortality achieved by the modified traveling screens as defined at 40 CFR 125.92(s) and demonstrating that the operation has been optimized to minimize impingement mortality. A complete description of the modified traveling screens and associated equipment must be included, including, for example, type of mesh, mesh slot size, pressure sprays and fish return mechanisms. A description of any biological data collection and data collection approach used in measuring impingement mortality must be included:
(A) Collecting data no less frequently than monthly. The Director may establish more frequent data collection;
(B) Biological data collection representative of the impingement and the impingement mortality at the intakes subject to this provision;
(C) A taxonomic identification to the lowest taxon possible of all organisms collected;
(D) The method in which naturally moribund organisms are identified and taken into account;
(E) The method in which mortality due to holding times is taken into account;
(F) If the facility entraps fish or shellfish, a count of entrapment, as defined at 40 CFR 125.92(j), as impingement mortality; and
(G) The percent impingement mortality reflecting optimized operation of the modified traveling screen and all supporting calculations.
(ii) If the applicant chooses to comply with 40 CFR 125.94(c)(6), the impingement technology performance optimization study must include biological data measuring the reduction in impingement mortality achieved by operation of the system of technologies, operational measures and best management practices, and demonstrating that operation of the system has been optimized to mi