Suggested Procedure for               Development of Spill               Prevention Control and               Countermeasu...
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A P I BULL*DLb 8 9             0 7 3 2 2 9 0 0087304 9                                                 Bulletin D16 Develo...
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  1. 1. Suggested Procedure for Development of Spill Prevention Control and Countermeasure Plans (To Assist Conformance to Requirements of Title 40, Code of Federal Regulations, Part 1 12.) API BULLETIN D I 6 (BUL 016) SECOND EDITION, AUGUST 1,1989 American Petroleum Institute 1220 L Street, Northwest Washington, DC 20005 1’ 1COPYRIGHT American Petroleum InstituteLicensed by Information Handling Services o
  2. 2. A P I BULL*DLb 8 3 m 0732230 0087233 3 m issued by AMERICAN PETROLEUM INSTITUTE Production Department FOR INFORMATION CONCERNING TECHNICAL CONTENT OF THIS PUBLICATION CONTACT THE API PRODUCTION DEPARTMENT, - 2535 ONE MAIN PLACE, DALLAS, TX 75202-3904 (214) 748-3841. SEE BACK COVER FOR INFORMATION CONCERNING HOW TO OBTAIN ADDITIONAL COPIES OF THIS PUBLICATION. Users of this publication should become familiar with its scope and content. This publication is intended to supplement rather than replace individual engineering judgment. OFFICIAL PUBLICATION REG. U.S. PATENT OFFICE Copyright @ 1989 American Petroleum InstituteCOPYRIGHT American Petroleum InstituteLicensed by Information Handling Services o
  3. 3. A P I BULL*DLb 8 9 m 0 7 3 2 2 9 0 0087300 L m TABLE OF CONTENTS Section Page Reference POLICY ... .............................................................................. 111 FOREWORD ................................................................................ iv INTRODUCTION ............................................................................. 1 GENERAL DISCUSSION. ADMINISTRATIVE SECTIONS. 40 CFR PART 112 .................. 1 Applicability ............................................................................... 1 Requirements for Preparation and Implementation of SPCC Plans ............................. 2 Certification ................................................................................ 2 Plan Availability ........................................................................... 2 Amendments ............................................................................... 3 Civil Penalties ............................................................................. 3 GUIDELINES FOR PLAN PREPARATION AND IMPLEMENTATION; SECTION 112.7; 40 ........................................................................... CFR PART 112 3 PART I. INSTRUCTIONS. GENERAL INFORMATION ......................................... 5 PART II. ALTERNATE A INSTRUCTIONS. ONSHORE FACILITY (EXCLUDING PRODUCTION) ................................................................ 6 Facility Drainage ........................................................................... 6 Bulk Storage Tanks ......................................................................... 6 Facility Transfer Operations. Pumping. and In-plant process .................................. 6 Facility Tank Car and Tank Truck Loading/Unloading Rack ................................... 6 Security .................................................................................... 7 PART II. ALTERNATE B INSTRUCTIONS. ONSHORE PRODUCTION FACILITY ............... 7 Facility Drainage ........................................................................... 7 Bulk Storage T a n k s . , ....................................................................... 7 Facility Transfer Operations ................................................................. 7 Oil Drilling and Workover Facilities ......................................................... 7 PART II. ALTERNATE C INSTRUCTIONS. OFFSHORE OIL DRILLING. PRODUCTION. OR WORKOVERFACILITY .................................................................. 8 Facility Drainage ........................................................................... 8 Sump System ............................................................................... 8 Separator and Treater Dump Valves ......................................................... 8 Tanks ...................................................................................... 8 Pollution Prevention Equipment and Systems ................................................ 8 Well Control Systems and Equipment ........................................................ 8 Written Instructions for Contractors ......................................................... 8 Flowlines .................................................................................. 8 Pipelines. .................................................................................. 8 APPENDICES . .OIL POLLUTION PREVENTION-NON-TRANSPORTATION RELATED ONSHORE AND OFFSHORE FACILITIES (40 CFR PART 112) .................................... App. A . .PROTECTION OF THE ENVIRONMENT-DISCHARGE OF OIL (40 CFR PART 110) .... App. B . .SUGGESTED MODEL FORMS (SPCC PLAN) ........................................... App. C .Part I. General Information .Part II, Alternate A, Design and Operating Information. Onshore Facility (Excluding Production) .Part II, Alternate B, Design and Operating Information, Onshore Oil Production Facility .Part II. Alternate C. Design and Operating Information, Offshore Oil Drilling. Production, or Workover Facility iCOPYRIGHT American Petroleum InstituteLicensed by Information Handling Services
  4. 4. _-_ - _- A P I BULLmDLb 87 9 0 7 3 2 2 7 0 0 0 8 7 3 0 1 3 9 TABLE OF CONTENTS (CONTINUED) Section .SPCC Plan, Attachment #i, Spill History .SPCC Plan, Attachment #2, Oil Spill Contingency Plans and Written Commitment of Manpower .SPCC Plan, Attachment #3, Onshore Facility Bulk Storage Tanks Drainage Systems .SPCC Plan, Attachment #4, Offshore Oil Drilling, Production, or Workover Facility Pollution Prevention Equipment and Systems .SPCC Plan, Attachment Bö, Offshore Oil Drilling, Production, or Workover Facility Well Control Systems and Equipment iiCOPYRIGHT American Petroleum InstituteLicensed by Information Handling Services
  5. 5. A P I BULL*DLb 89 m 0732290 0087302 5 m POLICY API PUBLICATIONS NECESSARILY ADDRESS PROBLEMS OF A GENERAL NATURE. WITH RESPECT TO PARTICULAR CIRCUMSTANCES, LOCAL, STATE, AND FEDERAL LAWS AND REGULATIONS SHOULD BE REVIEWED. API IS NOT UNDERTAKING TO MEET DUTIES O F EMPLOYERS, MANU- FACTURERS, OR SUPPLIERS TO WARN AND PROPERLY TRAIN AND EQUIP THEIR EMPLOYEES, AND OTHERS EXPOSED, CONCERNING HEALTH AND SAFETY RISKS AND PRECAUTIONS, NOR UNDERTAKING THEIR OBLIGATIONS UNDER LOCAL, STATE, OR FEDERAL LAWS. NOTHING CONTAINED IN ANY API PUBLICATION IS TO BE CON- STRUED AS GRANTING ANY RIGHT, BY IMPLICATION OR OTHERWISE, FOR THE MANUFACTURE, SALE, OR USE OF ANY METHOD, APPARA- TUS, OR PRODUCT COVERED BY LETTERS PATENT. NEITHER SHOULD ANYTHING CONTAINED IN THIS PUBLICATION BE CONSTRUED AS INSURING ANYONE AGAINST LIABILITY FOR INFRINGEMENT OF LET- TERS PATENT. GENERALLY, API STANDARDS ARE REVIEWED AND REVISED, RE- AFFIRMED, OR WITHDRAWN AT LEAST EVERY FIVE YEARS. SOME- TIMES A ONE-TIME EXTENSION OF TWO YEARS WILL BE ADDED TO THIS REVIEW CYCLE. THIS PUBLICATION WILL NO LONGER BE IN EFFECT FIVE YEARS AETER ITS PUBLICATION DATE AS AN OPERA- TIVE API STANDARD OR, WHERE AN EXTENSION HAS BEEN GRANTED, UPON REPUBLICATION. STATUS OF THIS PUBLICATION CAN BE ASCER- TAINED FROM THE AUTHORING PRODUCTION DEPARTMENT (TELE- PHONE 214-748-3841). CATALOG OF API PUBLICATIONS AND MATE- A RIALS IS PUBLISHED ANNUALLY AND UPDATED QUARTERLY BY AMERICAN PETROLEUM INSTITUTE, 1220 L ST., N. W., WASHINGTON, D.C. 20005 (TELEPHONE 202-682-8375). iiiCOPYRIGHT American Petroleum InstituteLicensed by Information Handling Services
  6. 6. - - -_I API BULL*DLb 87 0732270 0087303 7 W FOREWORD I n 1970 Congress enacted the Water Quality Improvement Act which stated t h a t the policy of the United States is t h a t there shall be no discharges of oil into the navigable waters of the United States. The discharge of harmful quantities of oil into navigable waters of the United States is prohibited. The current definition of what h a s been deter- mined to be a “harmful quantity’’ includes i n Title 40, Code of Federal Regulations, Part 110 (40 CFR Part llO)*, “Protection of Environment-Discharge of Oil”, those discharges which will cause a sheen or .:iscoloration of the surface of t h e water or a sludge or emulsion to be deposited beneath the surface of the water. Title 40, Code of Federal Regulations, Part 112 (40 CFR Part 112)*, “Oil Pollution Prevention-Non-transportation Related Onshore a n d Offshore Facilities”, was promulgated December 11, 1973 pursuant to Section 311 (j)(l)(C)of theFederal Water Polution Control Act Amendments of i972 which requires the establishment of procedures, methods, a n d equipment to prevent a n d contain discharges of oil. This bulletin h a s been developed by the American Petroleum Institute, Production Department, to assist oil a n d g a s producing operators i n their efforts to comply with the regulations i n 40 CFR Part 112.These regulations became effective on J a n u a r y 10,1974, a n d are applicable to non-transportation related onshore a n d offshore facilities which have discharged or, due to their location, could reasonably be expected to discharge oil into or upon the navigable waters of t h e u n i t e d s t a t e s or adjoining shorelines. As pertaining to offshore facilities, the regulations are limited to those facilities t h a t lie within, on, or under a n y of the navigable waters of the United States. Facilities located beyond the territorial seas are not covered by 40 CFR Part 112. These regulations require that operators of applicable facilities prepare a Spill Prevention Control and Countermeasure (SPCC) Plan for each production facility (which may include a portion or all of the producing facilities of each individual operator within a n oilfield) by July 10, 1974 unless a n extension is granted because compliance is not possible due to the nonavailability of qualified personnel or if there are delays i n construction or equipment delivery beyond the control and without the fault of the operator. Implementation of the individual SPCC Plans is to be accomplished by January 10, 1976 unless qualified person- nel are not available or if there are delays i n construction or equipment delivery beyond the control and without the fault of the operator. Attached are suggested forms, Part I and Part II (Alternates A, B, and Cl, which may be utilized and/or copied as necessary in the prep- aration of either single or multiple facility SPCC Plans. Regardless of the size or location of a n oil producer’s operation, i t is necessary that a n assessment be made of those operations to determine whether or not the provisions of the oil pollution prevention regulations are applicable. Basically, the criteria is that if i t can be reasonably expected that a discharge of oil a t a production facility, including a gasoline plant, will enter the navigable waters of the United States or adjoining shorelines that facility is subject to the regulations. The attached regulations and discussion will assist the operator in making the proper assessment. As is indicated by the title of the regulations their purpose is to prevent oil discharges from getting into navigable waters. The first line of defense is to urge the use of pollution prevention equipment and to train and educate operating personnel to reduce human errors so that accidental discharges may be reduced to a minimum. The second line of defense is secondary containment, where appropriate, to preverlt any accidental discharge from reach- ing navigable waters. Where secondary containment is not practicable, the operator must show that he has prepared a n adequate oil spill contingency plan and that management is in full support of the contingency plan with a commitment of necessary manpower and materials. This Second Edition supersedes a n d replaces the First Edition, March 1974 (Reissued February 1976). Attention Users: Portions of this publication have been changed from the previous edition. The location of changes have been marked with a bar i n the margin, as shown to the left of this paragraph. I n some cases t h e changes m a y be significant, while i n other cases the changes reflect minor editorial adjustments. The bar notations in the margins are pro- vided as a n aid to users as to those parts of this publication t h a t have been changed from the previous edition, but API makes no warranty as to the accuracy of such bar notations. *Available from Superintendent of Documents, U S . Government Printing Office, Washington, D.C. 20402. ivCOPYRIGHT American Petroleum InstituteLicensed by Information Handling Services
  7. 7. A P I BULL*DLb 8 9 0 7 3 2 2 9 0 0087304 9 Bulletin D16 Development of SPCC Plans 1 SUGGESTEDPROCEDUREFORDEVELOPMENTOF SPILL PREVENTION CONTROL AND COUNTERMEASURE PLANS (To s s i s t C o n f o r m a n c e to R e q u i r e m e n t s ofTitZe40,Code of Federal Regulations,Part 112.) A 1 INTRODUCTION The Federal W ater Pollution Control Act Amend- utilized and/or copied as necessary in the prepara- ments of 1972 require t h e Administrator of the tion of single or multiple facility SPCC Plans. Environmental Protection Agency (EPA), with The attached forms for use in preparation of other federal, state, and interstate agencies, to SPCC Plans were developed specifically for the oil enter into programs designed to prevent, reduce, or producing industry. The regulations require that eliminate pollution of the navigable waters of the owners or operators (including contractor opera- United States. On December 11, 1973, the EPA tors) of mobile drilling and workover rigs must published regulations for the prevention of pollu- also prepare and implement SPCC Plans for each tion of waters of the United States by oil emanat- rig. With the exception of offshore drilling and ing from non-transportation related onshore and workover rigs, the forms presented in this bulletin offshore facilities. The regulations are identified should not be assumed to be applicable for any as Title 40, Code of Federal Regulations, Part 112 other phase of industry, including drilling and (40 CFR Part 1121, “Oil Pollution Prevention- workover rigs used in onshore operations. The Non-transportation Related Onshore and Offshore form developed for offshore producing facilities is Facilities”, and became effective on January 10, also intended to be applicable to offshore drilling 1974. and workover rigs. Owners or operators of onshore These regulations require the preparation and drilling and workover rigs should review the regu- implementation of a Spill Prevention Control and lations and comply with requirements applicable Countermeasure (SPCC)Plan for all non-transpor- to their specific operations. Owners or operators of tation related facilities (onshore and offshore) facilities are advised to consult with their legal which have discharged or could reasonably be ex- counsel with respect to the applicability of the pected to discharge oil into the navigable waters of suggested procedure and forms. theunitedstates or the adjoining shorelines. This The objective of these regulations is to prevent bulletin has been prepared by the American Petro- the discharge of oil in harmful quantities into the I leum Institute, Production Department, to assist the oil and gas producing industry in understand- navigable waters of the United States or adjoining shorelines. The accomplishment of this objective ing the regulations and in developing the SPCC requires an assessment of each facility for the pos- Plans wherever they are needed. Included in this sibility of any such discharge of oil. Where such po- bulletin are: (a) a copy of the oil pollution preven- tential exists, the regulations urge that (a) em- tion regulations (40 CFR Part 1121, (b) dischargeof ployees be adequately trained to reduce the number oil regulations (40 CFR Part 1101, (c)suggested of human errors that often cause spills; (b) inspec- forms for usein preparation of SPCC Plans, (d) dis- tion procedures be implemented; (c) when appro- cussion of the regulations, and (e) instructions for priate, pollution prevention equipment be installed preparing SPCC Plans as required by the regula- and maintained; and (d) secondary containment, if tions. Attached are suggested forms, Part I and practicable, be provided t o contain any oil that may Part II (Alternates A, B, and C), which may be be spilled. GENERAL DISCUSSION (Administrative Sections of 40 CFR Part 112;Sections 112.1 - 112.6;Pages 34166-34167) APPLICABILITY the regulations (40 CFR Part 112) there is a copy of a Memorandum of Understanding Except for facilities listed below, a SPCC Plan between the Secretary of Transportation must be prepared by the owner or operator of on- and the Administrator of the EPA defining shore and offshore non-transportation related pro- transportation related and non-transporta- duction facilities engaged in drilling, producing, tion related facilities. gathering, storing, processing, refining, transfer- ring, distributing, and consuming oil and oil prod- (2) Facilities having a total above-ground stor- ucts. The exceptions to this requirement are as age capacity of 1,320 gallons or less of oil, follows: provided no single container has a capacity in excess of 660 gallons. (i) Equipment or operations of vessels or facili- ties which are subject to authority and con- (3) Facilities having a total storage capacity of trol of the U.S. Department of Transporta- 42,000 gallons or less and with such total tion. On page 34170 of the attached copy of storage capacity buried underground.COPYRIGHT American Petroleum InstituteLicensed by Information Handling Services
  8. 8. 2 American Petroleum Institute (4) Facilities which, due to their location, could (b) which are utilized by interstate travel- not reasonably be expected to discharge oil ers for recreational or other purposes. into or upon the navigable waters of the United States or adjoining shorelines. REQUIREMENTS FOR PREPARATION AND IMPLEMENTATION OP SPCC PLANS Non-transportation related production facilities include, but are not limited to, oil production lease SPCC Plans are to be prepared and maintained facilities, mobile or portable drilling or workover at an appropriate place near or at the facility by rigs operating in a fixed mode, portable fueling July 10, 1974, for facilities in operation on January facilities, and gas processing plants. Gas treating 10, 1974, or within 6 months of the date of first op- and compression operations integrally associated eration for newly constructed facilities. If it is not with oil production operations or gas processing possible to prepare the SPCC Plan within the re- plants are to be considered a part of the production quired period because of nonavailability of qual- lease or plant facility. ified manpower the operator may request an exten- sion of time from the EPA Regional Administrator, Individual SPCC Plans must be prepared by the setting forth the details of the request in a letter. owner or operator of each mobile or portable drill- ing or workover rig. These plans will apply from Operators are to implement the SPCC Plans as location to location and need not be redone each soon as possible after preparation, but no later than time the rig moves. Well and lease service opera- one year after date of first operation or by January tions such as paraffin and scale removal, etc., are to 10, 1975, whichever is the latest, If an operator be covered by the SPCC Plan prepared for the lease cannot comply with this time requirement due to production facility. nonavailability of qualified personnel or delay in construction or equipment delivery beyond his con- In order to determine which production facilities trol, he may request a n extension of time by a let- will require SPCC Plans, the owner or operator ter request to the EPA Regional Administrator. must make a determination of those facilities from “he letter must include: which a discharge could “reasonably be expected” to get into navigable waters or upon adjoining (i) a complete copy of the SPCC Plan; shorelines. Obviously, if a facility is far removed (2) a full explanation of the cause for any such from navigable waters the chance for a discharge delay and the specific aspects of the SPCC at that location getting into the navigable waters Plan affected by the delay; may be very remote. All facilities should be exam- (3) a full discussion of actions being taken or ined critically to determine if, in the judgment of contemplated to minimize or mitigate such the owner or operator, a discharge at that location delay; and could logically be expected to get into such water. (4) a proposed time schedule for the implemen- Among the factors the owner or operator should tation of any corrective actions being taken consider in making such determination are: or contemplated, including interim dates for completion of tests or studies, installation (i) prior spill history; and operation of any necessary equipment, or (2) location (proximity to navigable waters); other preventive measures. (3) potential size of discharge; CERTIFICATION (4) type of soil and terrain; and ( 5 ) frequency and amount of rainfall. Each SPCC Plan must be reviewed and certified by a Registered Professional Engineer. The engi- The phrase “reasonably be expected” means that neer must be familiar with the provisions of 40 the expectation is logical, rational, sensible, justifi- CFR, Part 112 and must have examined the facility able, credible, plausible, etc. and attest that the Plan has been prepared in ac- The term “navigable waters” is defined in the cordance with good engineering practices. It is not attached regulations (40 CFR Part 112) in Section necessary by this regulation that the engineer be 112.2 (k) (see page 34165). Generally speaking, registered in the state in which the facility is lo- every body of water or continuous stream should cated. However, for the protection of the Registered be considered as navigable. The definition includes Professional Engineer local licensing requirements the following: should be ascertained. PLAN AVAILABILITY (i) waters that are navigable in fact; (2) waters declared navigable by a Federal The operator of a facility for which a SPCC Plan agency or court; is required must maintain a complete copy of the (3) tributaries of navigable waters; Plan at the facility, if manned at least 8 hours per (4) interstate waters; and day, or at the nearest field office if unmanned. The ( 5 ) intrastate lakes, rivers, and streams Plan must be made available to EPA personnel for (a) from which fish or shellfish are taken on-site review anytime during normal working and sold in interstate commerce, or hours.COPYRIGHT American Petroleum InstituteLicensed by Information Handling Services
  9. 9. A P I BULL*DLb 8 9 m 0 7 3 2 2 9 0 008730b 2 M Bulletin D16: Development of SPCC Plans 3 AMENDMENTS not general. For instance, it would be inade- The owner or operator is required to amend the quate to report simply that the cause of a Plan for the following reasons: spill was the failure.of a storage tank. The failure analysis should indicate in some de- (1) when required by the EPA after review of tail the nature of failure that caused the the Plan, submitted because of a spill event; spill. (2) whenever there is a change in facility design, (9) The corrective actions and/or countermeas- construction, operations, or maintenance ures taken, including an adequate descrip- which materially affects the potential for an tion of ,equipment repairs and/or replace- oil spill; or ments. (3) the owner or operator is required to review (10)Additional preventive measures taken or each SPCC Plan at least once every three contemplated to minimize the possibility of years, and an amendment is required if such recurrence. review indicates more effective control and (1 Such other information as the EPA Regional 1) prevention technology will significantly re- Administrator may require. duce the likelihood of a spill event (and if A complete copy of all information provided to such technology has been field proven). EPA must also be sent at the same time to the state Commencing January 10, 1975, unless an exten- agency in charge of water pollution control ac- sion of time has been granted by the EPA Regional tivities. The state agency may review the informa- Administrator, the operator must submit the SPCC tion and make recommendations to EPA to prevent Plan with any amendments to EPA and to the ap- and to contain discharges of oil from the facility. propriate state agencies whenever a facility has: The EPA will review the information and any rec- ommendations made by the state agency and may (1) discharged more than 1,000 U. S. gallons require the operator t o amend the SPCC Plan. (approximately 24 barrels) into navigable When EPA proposes to require an amendment to waters in a single spill event; or the Plan, the operator will be notified by certified (2) discharged oil in harmful quantities, as de- mail or by personal delivery. The EPA will specify fined in 40 CFR Part l í o , into navigable the terms of such amendment. Within 30 days from waters in two reportable spill events within receipt of this notice, the operator may submit writ- any 12-month period. ten information, views, and arguments on the pro- Within 60 days of the occurrence of either of posed amendment requirement. After considering these two conditions the operator must submit to all material presented, EPA will notify the operator the EPA Regional Administrator the following: of the amendment required or will rescind the notice. The amendment required becomes a part of (1) Name of the facility. the SPCC Plan 30 days after such notice, unless the (2) Name of the owner or operator of the facility. operator appeals, and the operator must implement (3) Location of the facility. the amendment as soon as possible but not later (4) Date of initial facility operation (date of first than six months after the amendment becomes a production or first gas plant start-up). part of the Plan. ( 5 ) Maximum storage or handling capacity of the facility and current normal daily All SPCC Plan amendments, except those pro- throughput. posed by the EPA Regional Administrator, must (6) Description of the facility, including maps, be certried by a Registered Professional Engineer. flow diagrams, and topographical maps. (7) A complete copy of the SPCC Plan with any amendments. CIVIL PENALTIES (8) The cause of such spill, including a failure analysis of the system or subsystem in which Owners or operators of facilities who violate the the failure occurred. Lease production facili- requirements of the regulations relating to the ties may be divided into drilling, production, preparation, implementation, and amendments to and gathering systems for identification pur- SPCC Plans are liable for a civil penalty of not poses in reporting to EPA. These major sys- more than $5,000 for each day that such violation tems can be broken downinto various com- continues. The EPA Regional Administrator may ponents or subsystems. The failure analysis assess and compromise such civil penalty. No pen- is to examine and explain the reason for the alty will be assessed until the owner or opera- failure resulting i n t h e spill event. The tor has been given notice and an opportunity for analysis should be explicit, definitive, and hearing. GUIDELINES FOR PLAN PREPARATION AND IMPLEMENTATION (Section 1 2 7 40 CFRPurt 112;Pages 34167-34170) 1.; Guidelines for the preparation and implementa- tion of a SPCC Plan are given in Section 112.7 of I the regulations (40 CFB Part 112).The Plan is to be a carefully thought-out Plan prepared in accord-COPYRIGHT American Petroleum InstituteLicensed by Information Handling Services
  10. 10. A P I BULL*DLb 8 7 W 0732270 0087307 4 4 American Petroleum Institute ance with good engineering practices and which for offshore non-transportation related has the full approval of management at a level of production facilities, located in, on, or authority to commit the necessary resources. If the under any of the navigable waters of the Plan calls for additional facilities or procedures, United States and mobile drilling and methods, or equipment not yet fully operational, workover rigs while they are operating these items are to be discussed separately. The within the navigable waters. It is not details of installation and operational start-up necessary, by 40 CFR Part 112, to p r e should be explained. pare SPCC Plans for facilities that are located beyond the territorial seas. So The suggested forms as attached in Part I and many of the provisions in Section 112.7 Part II (Alternates A, B, and C), were developed to (e)(7)(seepage34169)of40 CFR Part112 assist the oil producing industry in preparation of (attached) are applicable to both produc- SPCC Plans for onshore and offshore facilities of a tion and drilling or workover operations non-transportation nature which have discharged that it is thought that one form should be or, due to their location, could reasonably be ex- adequate for all such facilities. pected to discharge oil into or upon the navigable waters of the United States or adjoining shorelines. A completed Plan utilizing the attached sug- It is not necessary that SPCC Plans be prepared gested forms will consist of three parts: utilizing these particular forms. However, these suggested forms may be utilized and/or copied as (1) Part I, General Information. necessary in the preparation of either single or (2) Part II, Design and Operating Information multiple facility SPCC Plans. The use of these sug- (Alternate A, B, or Cl. gested forms will simplify preparation and provide (3) Appendix-supplemental information rec- uniformity in completed Plans. ommended by the guidelines, such as inspec- tion records, written procedures, contingency The forms that have been developed are: plans, maps, etc. (1) PART I, GENERAL INFORMATION. This To assist in the differentiation between “onshore” form is for recording information of a gen- and “offshore” facilities the following comments eral nature and is applicable to all facilities. may be helpful: ‘<Offshore” facilities mean those facilities that are (2) PART II, DESIGN AND OPERATING IN- located in rivers, lakes, bays, estuaries, territor- FORMATION. There are three different or ial waters of the United States, or in marsh areas alternate forms developed for the purpose of where some or all of the facility is over or in recording information specific to the design water. There will be some locations where the de- and operation of a facility, as such design termination of whether the facility is “offshore” and operation pertain to the prevention of or “onshore” will be doubtful, e.g., inland rivers; discharge of harmful quantities of oil into small, shallow lakes; etc. The question of proper navigable waters. The forms are for three identification of the facility in doubtful locations different classifications of facilities as should be referred to appropriate legal counsel. follows: The guidelines provide for inspections of certain (a) ALTERNATE A, ONSHORE FACILITY items of equipment to determine the state of their (EXCLUDING PRODUCTION). This condition and ability to adequately prevent the ac- form is for onshore facilities that are not cidental discharge of oil as a result of failure. The oil producing facilities, such as gasoline plants. procedures for conducting inspections should be written in the SPCC Plan and a record of such in- spections should be made a part of the Plan and (b) ALTERNATE B, ONSHORE OIL PRO- retained for a period of three years. DUCTION FACILITY. This form is for onshore facilities involved in the pro- A production facility (onshore or offshore) may duction of oil, including condensate. include all operations within a single geographical Includes all producing facilities such as field. However, if it is appropriate, a facility may be wells, gathering lines, separation and subdivided and a SPCC Plan prepared for each di- treating, and storageor custody transfer. vision. The SPCC Plan prepared for a gas plant, This form, without review and study, whether located onshore or offshore, should follow the format of the form designated “Part II, Alter- I should not necessarily be presumed to be adequate to meet all the requirements nate A, Onshore Facility (Excluding Production)”. for preparation of SPCC Plans for on- shore drilling and workover rigs. The forms are designed so that the preparing person can usually answer “YES’: “NO”,or “NA” (c) ALTERNATE C, OFFSHORE OIL (not applicable) to statements referring to the D R I L L I N G , P R O D U C T I O N , OR guideline provisions of the regulation. Space is WORKOVER FACILITY. This form is provided for discussion of the operations orproce-COPYRIGHT American Petroleum InstituteLicensed by Information Handling Services
  11. 11. API.BULL*DLb 8 9 W 0732270 0087308 b W Bulletin D16: Development of SPCC Plans 5 response to a statement will require discussion. A some cases the guidelines provide for additional “YES’or “NA” response also m a y require discus- information, and in these cases a n acceptable sion for clarification. I f additional space for dis- attachment is provided as a part of this Bulletin. 1. Enter a descriptive name for the area to be in- a result of the prediction, appropriate containment cluded in the Plan. The name could be the field and/or diversionary structures or equipment to name if all operations within one field are included, prevent discharge oil from reaching navigable or a field name with the name of the specific opera- waters should be provided, when practicable. I n tions included. some cases, a narrative description of flow and the containment method will be sufficient. In more 2. Classify the facility as: (a) onshore facility-gas complex situations, especially those involving plant (or other); (b) onshore production fadlity; (c) multiple operations, a n appropriate map may be offshore production facility; (d) offshore drilling (or attached to show locations of the potential sources workover) facility; or (e) offshore production fa- of oil discharges, direction of flow, and locations of cility-gas plant, any navigable waters. 3. The facility location should include the county When it is determined that the installation of (parish) and state and the distance and direction structures or equipment to prevent discharged oil from a nearby town. from reaching navigable waters is not practicable 4. Enter the name of the person (corporation, for the facility, the owner or operator should ex- company, partnership, individual, etc.) responsible plain why and provide the following: for the facility operations and the address to which correspondence regarding the facility should be (1) A strong oil spill contingency plan. sent. (2) A written commitment of manpower, equip- 5. Enter the name and title of the designated ment, and materials required to expedi- person who is accountable for oil spill prevention tiously control and remove any harmful and who reports to line management. In various quantities of oil discharged. Attachment #2 situations, this person could be a company em- is provided to assist i n meeting this ployee such as a superintendent or foreman, or an requirement. owner or operator’s agent with similar respon- sibilities and authority. The regulations (40 CFR Par€112) state that the I Plan should provide for inspections of some opera- 6. If a facility has experienced one or more re- tions. The inspections should be in accordance portable oil spills within the 12 months prior t o the with written procedures developed for the facility effective date of the regulation (January 10, 19741, by the owner or operator. These written procedures a written description of each such spill, the correc- and a record of the inspections signed by the tive action taken, and the plans for preventing re- appropriatesupervisor or inspector should be made currence must be included in the Plan. Attachment a part of the SPCC Plan. The written procedures #1 may be used for this purpose. for the inspections should be prepared for the indi- vidual facility by the owner or operator and should The overall Plan must have full approval of be attached to the appropriate inspection record. management a t a level with authority to commit the necessary resources. Owners or operators of a facility are responsible under the guidelines for properly instructing their A Registered Professional Engineer must certify personnel in (a) the operation and maintenance of that he has reviewed the Plan, has examined the equipment to prevent the discharge of oil to navig- facility, is familiar with the provisions of the regu- able water, and (b) the applicable pollution control lations (40 CFR Part 112), and can attest that the laws, rules, and regulations affecting the facility. SPCC Plan has been prepared in accordance with Owners or operators should schedule and conduct good engineering practices. spill prevention briefings for their operating per- Where experience indicates a reasonable poten- sonnel at intervals frequent enough to assure ade- tial for equipment failure, the Plan for a facility quate understanding of the SPCC Plan. These should include a prediction of the direction, rate of briefings should highlight and describe known spill flow, and total quantity of oil which could be dis- events or failures, malfunctioning components, and charged as a result of each major type of failure. As recently developed precautionary measures.COPYRIGHT American Petroleum InstituteLicensed by Information Handling Services
  12. 12. -- API BULLmDLh 89 0732270 O087309 ô a 6 American Petroleum Institute PART II, ALTERNATE A INSTRUCTIONS ONSHORE FACILITY (EXCLUDING PRODUCTION) This form may be used in the preparation of tions, or inspection by a system of non-destructive SPCC Plans for non-production onshore facilities, shell thickness gauging. Appropriate records of the such as gasoline plants. inspections should be maintained. Records need not be maintained for the regular, routine observations A. Facility Drainage made by the plant workmen. Diked storage areas should have manual valves, When leakage from defective internal heating manually activated pumps or ejectors, or other ac- coils could discharge oil into an open watercourse, ceptable alternatives to drain or empty retained such leakage should be controlled by (a) monitoring storm water. The condition of the water should be the steam return or exhaust lines for the presence checked before drainage to ensure that no oil is of oil; (b) passing the steam return or exhaust lines discharged. through a settling tank, skimmer, or other separa- Plant drainage systems for undiked areas should tion system; or (c) replacing the internal heating flow, if possible, into either (a) ponds, lagoons, or coil with an external heating system. catchment basins designed to retain oil or return it to the facility, or (b) a diversion system at the final Each bulk storage tank should be externally ex- discharge of all in-plant ditches that could contain amined frequently for signs of deterioration and an uncontrolled spill and return the oil to the plant. leaks. All tank installations should be fail-safe Where drainage waters are treated in more than engineered, as far as practicable. Consideration one treatment unit, natural hydraulic flow should should be given to the use of high-liquid-level be used. If pump transfer is used, two “lift” pumps alarms with an audible or visual signal, high-level should be provided. If the treatment is continuous, pump cutoff devices, fast response system for de- one of the pumps should be permanently installed. termining liquid levels, equalizing lines between Drainage of rain water from dikes into a storm tanks, or other automatic safety devices. drain or into an emuent discharge which empties Plant effluents which are discharged into a into an open watercourse, lake, or pond may bypass watercourse should have disposal facilities ob- the in-plant treatment system if (a) the bypass served frequently enough to detect any possible valve is normally sealed closed, (b) the effluent is system upset that could cause an oil discharge. Vis- inspected t o ensure compliance with applicable ible oil leaks which result in a loss of oil from tank water quality standards and that no harmful dis- seams, gaskets, rivets, or bolts should be promptly charge will occur, (c) the opening and resealing of corrected. the bypass valve is conducted under responsible C. Facility Transfer Operations, Pumping, and supervision, and (d) adequate records are kept of In-plant Process such events. Buried piping installations should have a protec- B. Bulk Storage Tanks tive wrapping and coating and should be cathodi- Bulk oil storage tank construction and material cally protected if soil conditions warrant. If a sec- should be compatible with the oil stored and the tion of buried line is exposed for any reason, it storage conditions such as pressure, temperature, should be inspected for condition, If corrosion dam- etc. age is found, additional inspection and corrective action should be taken as indicated by the mag- Secondary containment should be provided for nitude of the damage. When a pipeline is not in the capacity of the largest single tank plus a suffi- service or is in standby service for a n extended cient allowance for precipitation. Dikes, curbs, and time, the terminal connection a t the transfer point pits are commonly used for this purpose. Dikes should be capped or blind-flanged. Pipe supports should be sufficiently impervious to contain oil. In should be properly designed to minimize abrasion considering the additional volume to be provided to and corrosion and allow for expansion and contrac- take care of precipitation, the determination should tion. All above-ground valves and pipeline should consider the greatest amount of rainfall that may be subjected to regular examination, Vehicle traffic reasonably be expected to occur in a storm. An al- should be warned andíor regulated t o assure no ternative system could consist of a drainage trench danger to above-ground piping. arranged so that a spill could terminate and be con- tained in a catchment basin. D. Facility Tank Car and Tank Truck Loading/ Unloading Rack New metallic tanks buried underground should Tank car and tank truck loadinghnloading rack be protected from corrosion by coatings, cathodic procedures should meet the minimum requirements protection, or other effective methods compatible established by the Department of Transportation with local soil conditions. Such tanks should be pressure tested a t regular intervals. Partially (refer to 49 CFR Parts 171,173,174,177, 179). and * I A quick drainage system should be provided in buried metallic tanks should be avoided unless loadinghnloading areas. The containment sys- buried portions are adequately protected. tem should be designed to hold at least maximum Above-ground tanks should be subjected to ap- propriate integrity testing. Appropriate procedures might include hydrostatic testing, visual inspec-COPYRIGHT American Petroleum Institute *Available from Superintendent of Documents U.S. Govern- ment Printing Office, Washington, D.C. 20402. ILicensed by Information Handling Services
  13. 13. . API BULL*DLb 89 m 0732290 0087330 4 m Bulletin D16: Development of SPCC PIans 7 capacity of any single tank truck compartment should use as security measures, fences and locked loaded or unloaded in the plant. A n interlocked and/or guarded gates when the plant is not in warning light, a physical barrier system, or warn- production or is unattended. Other measures ing signs should be provided in loadinghnloading should include lockedvalves on tanks if the valves areas to prevent vehicle departure before complete could permit a spill, secured or electrically isolated disconnect. Drains and outlets on tank cars and starter controls on oil pumps, capped or blind- tank trucks should be examined for leakage prior flanged loadinghnloading connections of oil pipe to filling. lines when not in service, and lighting adequate to permit surveillance of the facility. The lighting E. Security around the facility should be discussed in the All plants (excluding oil production facilities) SPCG Plan. I PART II, ALTERNATE B INSTRUCTIONS, ONSHORE OIL PRODUCTION FACILITY This form may be used to prepare a SPCC Plan Tanks should be visually examined by a compe- for oil production facilities located onshore, It has tent person for condition and need for maintenance been developed specifically for producing opera- on a scheduled, periodic basis. Such inspection tions and should not necessarily be presumed to be should incIude the foundation and supports of tanks I adequate for application to onshore drilling or workover rigs. that are above the surface of the ground. These ex- aminations should be more comprehensive than the A. Facility Drainage observations made by pumpers in their routine activities. Diked storage areas should have manual valves or other acceptable alternative on drains. The con- Both new and old tank battery installations dition of retained storm water for the presence of should be properly designed and equipped to pre- oil should be determined before drainage. vent the accidental discharge of oil. Fail-safe en- All drains from tank battery or central treating gineering features which should be considered in station secondary containment structures should construction or modification include adequate siz- be closed and sealed except during drainage of ing of tanks, use of overflow equalizing lines, ade- rain water. quate vacuum protection, and the use of high- Drainage of rain water from dikes into a storm liquid-level sensors when a computer production drain or into an effiuent discharge which empties control system is used. into a n open watercourse, lake, or pond may bypass C.Facility Transfer Operations the facility treatment system if (a) the bypass valve is normally sealed closed, (b) the effiuent is in- In the oil and water transfer operations that take spected to ensure compliance with applicable water place within the facility, all above-ground valves quality standards and that no harmful discharge and pipelines should be examined on a scheduled will occur, (c) the opening and resealing of the basis for general conditions of items such as flange bypass valve is conducted under responsible super- joints, value glands and bodies, drip pans, pipeline vision, and (d) adequate records are kept of such supports, pumping well polish rod stuffing boxes, events. Field drainage ditches, road ditches, and oil bleeder and gauge valves, etc. Salt water disposal traps or skimmers should be inspected at regular facilities should be examined frequently, particu- intervals for accumulations of oil that may have es- larly following changes in pressure or temperature caped from small leaks. Accumulated oil should be conditions that could cause line failure. Records returned to storage ’or disposed of by a n approved should be kept of flow line repairs and used by the method. operator as a basis for a maintenance and replace- ment program designed to eliminate or minimize B Bulk Storage Tanks . accidental oil discharges. Oil storage t a n k construction a n d material should be compatible with the oil stored and the D. Oil Drilling & Workover Facilities storage conditions auch as pressure, temperature, During drilling or workover operations, the pro- etc. duction facility operator should ascertain that a Secondary containment should be provided for blowout preventer assembly and well control sys- the capacity of the largest single tank plus a suffi- tem is installed that will be capable of controlling cient allowance for precipitation. Dikes, curbs, and any wellhead pressure anticipated,[The drilling or ~ pits are commonly used for this purpose. Dikes workover rig owner or operator (contractor) must should be sufficiently impervious to contain oil. In prepare and implement a SPCC Plan that will per- considering the additional volume to be provided to tain to the drilling or workover rig.] The blowout take care of precipitation, the determination should preventer installation should be in accordance consider the greatest amount of rainfall that may be reasonably expected to occur in a storm. An al- ternative system could consist of a drainage trench with requirements of state and other applicable rules and regulations. The degree of well control system redundancy and “fail-safe” valving design I arranged so a spill could terminate and be con- should vary with hazard exposure and probable tained in a catchment basin. consequences of failure.COPYRIGHT American Petroleum InstituteLicensed by Information Handling Services
  14. 14. A P I BULLxDLh 8 7 0 7 3 2 2 7 0 00873LL b 8 American Petroleum Institute PART II, ALTERNATE C INSTRUCTIONS OFFSHORE OIL DRILLING, PRODUCTION, OR WORKOVER FACILITY This form may be used in preparation of SPCC pressure sensors, etc. should be inspected and Plans for offshore production facilities and drill- tested at periodic intervals. ing or workover rigs used in offshore operations. The form was designed specifically for producing F. Well Control Systems and Equipment facilities but is also thought to be adequate for Producing Wells.Type of surface and subsurface I application to offshore drilling and workover rigs. shut-in valves and devices in use at the facility should be described as to method of operation and A. Facility Drainage control (refer to Attachment #5). I All sources of drips and small spillages of oil on Drilling and Workover Operations. During drill- offshore platforms should be protected with drains ing or workover operations, a blowout preventer and drip pans to catch the oil before it can enter the assembly and well control system should be in- water. Drip pans should be observed at regular in- stalled that is capable of controlling any wellhead tervals and emptied when necessary to make sure pressure anticipated. Casing and blowout preven- they do not fill to overflowing. Drains should empty ter installations should be in accordance with into sumps which should be emptied as often as requirements of applicable rules and regulations. I necessary to prevent overflowing. The degree of well control system redundancy B. Sumpsystem and “fail-safe” valving design should vary with hazard exposure and probable consequences of The sumps provided as overflow and spill collec- failure. tion equipment should be large enough to allow protection against accidental spillages. Some ade- G. Written Instructions for Contractors quate alternate means should be provided for re- The regulations state that in order that there will I moving the liquid caught in the sumps in case the be no misunderstanding of the joint and separate primary sump pump becomes inoperative. The duties and obligations to perform work in a safe pump and start-up device should be inspected and and pollution-free manner, written instructions tested at regular intervals to ensure they are func- should be prepared by the owner or operator for tional at all times. contractors and subcontractors to follow whenever contract activities include servicing a well or sys- C. Separator and Treater Dump Valves tems appurtenant to a well or pressurevessel. Such If the predominant mode of failure of dump instructions and procedures should be maintained valves used on separators and treaters a t a n at the facility. Under certain circumstances, con- offshore facility is in the closed position, the poten- tractor activities may require intervention by a n tial for pollution is not great if the pressure relief authorized representative of the owner or operator line extends to a surge tank or scrubber which to prevent a spill event. (Appropriate legal counsel would catch any fluid overflowing through the re- should be consulted regarding implementation of lief line. this section.) H. Flowlines D. Tanks 1. All headers should be equipped with check All tanks should be equipped with protective de- valves on individual flowlines. vices to reduce the potential for overflowing or rup- 2. If the shut-in wellhead pressure is greater turing and, thus, discharging oil upon the surface than the working pressure of the flowline from the of the water, Atmospheric storage or surge tanks well and/or the header valves associated with that should be equipped with high-liquid-level sensors individual flowline, the flowline should be equipped or other acceptable alternatives to prevent spills, with a pressure sensing device and shut-in valve and pressure tanks should have high and low pres- at the wellhead unless a pressure relief system is sure sensors to activate alarms and/or control flow provided. or other acceptable alternatives to prevent spills. Tanks should be adequately protected internally I. Pipelines and externally from corrosion, as required to pre- 1. All pipelines appurtenant to the facility vent leakage or spillage. should be protected against corrosion. Methods of providing such protection should be described. E. Pollution Prevention Equipment and Sys- 2. Submarine pipelines associated with the facil- tems ity should be adequately protected against en- Inspection and testing procedures for pollution vironmental stresses and other activities such as prevention equipment and systems should be de- fishing operations, veloped and a copy of such procedures maintained 3. Submarine pipelines should be inspected for at the facility (see Attachment #4). Such equip- failures periodically, A documented record of such ment as high and low level sensors, high and low inspections should be maintained a t the facility.COPYRIGHT American Petroleum InstituteLicensed by Information Handling Services
  15. 15. A P I BULLmDLb 8 9 = 0732290 0087322 & ~ ~~ APPENDIX A TUESDAY, DECEMBER 11, 1973 WAStiIffiTW, O S . Volume 38 m Number 237 PART II ENVIRONMENTAL PROTECTION AGENCY OIL POLLUTION PREVENTION Non-Transportation Related Onshore and Offshore Facilities No.a37-Pt. II-1COPYRIGHT American Petroleum InstituteLicensed by Information Handling Services
  16. 16. A P I BULLmDLb 8 9 m 0 7 3 2 2 9 0 0087333 T+m APPENDIX A 34164 RULES AND REGULATIONS Title 40-Protection of the Environment tion, could reasonably be expected to dis- Section 1 1 2 . 3 ~ (1) (5 112.3(e)(1) in ) charge oil into or upon the navigable the proposed regulation) was changed t o CHAPTER I-ENVIRONMENTAL waters of the United States or adjoining include the nonavailabilitu of aua.lified PROTECTION AGENCY personnel as a reason f o i the Regional shorelines. SUBCHAPTER D-WATER PROGRAMS Sections 112.1(b), 112.l(d) (4) and Administrator granting an extension of PART 1 1 2 4 I L POLLUTION PREVENTION 112.3 are now consistent. time. Section 112.l(d) (1) was expanded to D. Section 112.4-Amendment of spill Non-transportation Related Onshore and further clarify the respective authori- prevention control and countermeasure Offshore Facilities plans by Regional Administrator. Section ties of the Department of Transporta- Notice of proposed rule making was tion and the Environmental Protection 112.4(a) ( l l ) ,permits the Regional Ad- published on July 19, 1973, containing Agency by referring to the Memorandum ministrator to require that the owner or proposed regulations, required by an of Understanding between the Secretaiy operator furnish additional information pursuant to section 311(j) (1)(C) of the of Transportation and the Administra- to EPA after one or more spill event has Federal Water Pollution qontrol A t, tor of the Environmental Protection occurred. The change limits the request as amended (86 Stat. 868, 33 U.S.C. 1251 Agency (Appendix). for additional information to that per- et seq.) , (FWPCA),to prevent discharges Section 112.l(d) (2), the figure for tinent to the SPCC Plan or to the pollu- of oil into the navigable waters of the barrels was converted to gallons, a unit tion incident. United States and to contain such dis- of measure more familiar to the public, Section 112.4(b) now reads “Section charges if they occur. The proposed reg- and now reads “42000 gallons.” 112.4 * * *”,not“Thissubsection * * *” ulations endeavor to prevent such spills Section 112.1(d) (3), exemption for Section 112.4(e) allowed the Regional bv establishing Drocedures, methods and facilities with nonburied tankage was Administrator to require amendments eiuipment reqüirements of owners or OP- extended to 1320 gallons in aggregate to SPCC Plans and specifies that the erators of facilities engaged in drilling, with no single tank larger than 660 gal- amendment must be incorporated in the producing, gathering, storing, processing, lons and applies to all oils, not just heat- Plan within 30 days unless the Regional refining, transferiing, distributing, or ing oil and motor fuel. Tanks of 660 Administrator specifies an earlier effec- consuming oil. gallons are the normal domestic code size tive date. The change allows the Regional Written comments on the proposed for nonburied heating oil tanks. Build- Administrator to specify any appropri- regulations were solicited and received ings may have two such tanks. Facilities ate date that is reasonable. from interested parties. I n addition, a containing small quantities of oil other Section 112.4(f). A new 5 112.4(f) has number of verbal comments on the pro- than motor fuel or heating oil would been added which provides for an appeal posal were also received. The written also be exempt, thus making this con- by an owner or operator from a decision comments are on file a t the Division of sistent with the definition of oil in § 112.2. rendered by the Regional Administrator Oil and Hazardous Materials, Office of B. Section 112.2-Definitions. Section on an amendment to an SPCC Plan. The Water Program Operations, U.S. En- 112.2(1), the term “navigable waters” appeal is made to the Administrator of vironmental Protection Agency, Wash- was expanded to the more descriptive EPA and the paragraph outlines the pro- ington, D.C. definition used by the National Pollutant cedures for making such an appeal. All of the comments have been given Discharge Elimination System. E. Section 112.5-Amendment of spill careful consideration and a number of Section 112.2(m), the U.S. Coast prevention control and countermeasure changes have been made in the rerala- Guard definition of the term “vessel” plans by owners or operators. Section tion. These changes incorporate either was included. This term i used in the s 112.5cb) required the owner or operator suggestions made in bhe comments or regulation and the definition is consist- to amend the SPCC Plan every three ideas initiated by the suggestions. ent with the Department of Transpor- years. The amendment required the in- Some comments reflected a misunder- tation regulations. corporation of any new, field-proven standing of the fundamental principies C. Section 112.3-Requirements for the technology and had to be certified by a of the regulation, specifically as they ap- preparation and implementation of spill Professional Engineer. plied to older facilities and marginal op- prevention control and countermeasure The change requires that the owner erations. During the development of the plans. A new paragraph (c) wm added or operator review the Plan every three regulation it was recognized that no to 5 112.3 which applies to mobile or port- years to see if it needs amendment. New single design or operational standaid can able facilities subject to the regulation. technology need be incorporated only if be prescribed for all non-transportation These facilities need not prepare a new it will significantly reduce the likelihood related facilities, since the equipment Spill Prevention Control and Counter- of a spill. The change will prevent friv- and operational procedures appropriate measure Plan (SPCC Plan) each time the olous retrofitting of equipment to facili- for one facility may not be appropriate facility is moved to a new site, but may ties whose prevention plans are working for another because of factors such as prepare a general plan, identifying good successfully, and Ml1 not require engi- function, location, and age of each facil- spill prevention engineering practices (as neering certification unless an amend- ity. Also, new facilities could achieve a outlined i n the guidelines, 8 112.7), and ment is necessary. higher level of spill prevention than older implement these practices at each new Section 112.5(c), this paragraph re- facilities by the use of fail-safe design location. quired thak the owner or operata, amend concepts and innovative spill prevention Section 112.3(a), (b) and (f) (which his SPCC Plan when his facility became methods and procedures. It was con- was 5 112.3(e) in the proposed rule mak- subject to 5112.4 (amendment by the cluded that older facilities and marginal ing) have been modified to allow exten- Regional Administrator). This para- operations could develop strong spill con- sions of time beyond the normally speci- graph has been removed. It is inconsist- tingency pians and commit manpower, fied peiiods to apply to the preparation ent to require the owner or operator to oil containment devices and removal of plans as well as to their implementa- independently amend the Plan while the equipment to compensate for inherent tion and to remove the time limitation Regional Administrator is reviewing it weaknesses in the spill prevention plan. of one year for extensions. Extensions for possible amendment. ’Appropriate changes were made in the may be allowed for whatever period of F. Section 112.6-CMl penalties. There regulation to simplify, clarify or correct time considered reasonable by the Re- are no changes in this section. deficiencies in the proposal. gional Administrator. G . Section 112.7-Guidelines for the A discussion of these changes, section Section 112.3(e) (which was 5112.3 preparation and implementation of a by section follows: spill prevention control and counter- A. Section 112.14enerul applicabil- (d) in the proposed iule making) was ity. Section 112.l(b), the “foreseeabil- modified to require the maintenance of measure plan. Numerous changes have ity provision”, contained in ,112.1(d) (4) the SPCC Plan for inspection at the fa- been made in the guidelines section; the cility only if the facility was noimally changes have been primarily: was added to paragraph 112.1cb). As 1. To correct the use of language in- modified, the regulation applies to non- manned. If the facility is unmanned, the consistent .with guidelines. For example, transportation-related onshore and off- Plan may be kept. at the nearest field the word “shall” has been changed t o shore facilities which, due to their loca- office. “should” in 8 112.7(a) through (e). FEDERAL REGISTER, VOL. 38, NO. 237-TUESDAY, DECEMBER 11, 1973COPYRIGHT American Petroleum InstituteLicensed by Information Handling Services

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