Bilag 5: Sample Spill Prevention Control and Countermeasure Plan (SPCC) – Arbejdsrapport fra Miljøstyrelsen Nr. 12 2008 – Baggrundsrapport om miljøkrav til store olielagre

Baggrundsrapport om miljøkrav til store olielagre

Bilag 5

Sample Spill Prevention Control and Countermeasure Plan (SPCC)

Efter US Environmental Protection Agency: 1998

The following is a sample SPCC Plan for a bulk oil storage facility (Note: other requirements apply to oil production, drilling, and workover facilities). This fictional sample is intended to serve as an example for facilities that are required to prepare an SPCC Plan. Individual facilities are different so each SPCC Plan will be different, and the level of detail in each Plan will be based on the design and size of the facility. A site diagram or diagrams which illustrate the design and organization of a facility (e.g., drainage patterns, locations of spill equipment, etc.) should be included. In this example, the requirements for the SPCC Plan found in 40 CFR 112.7 are enclosed in a box. Sample language for the example facility described as the Neverspill Oil Corporation follows the regulatory citations.

SAMPLE
SPILL PREVENTION CONTROL AND
COUNTERMEASURE PLAN

FOR
Neverspill Oil Corporation

Clean City Bulk Storage Terminal
2000 Prevention Street
Clean City, California 90000
Original Date of Plan: January 1, 1974
Date of Last Plan Amendment/P.E. Certification: June 30, 1995
Date of Last Plan Review: January 1, 1998
Designated person accountable for spill prevention:
Kelly Neverspill
Facility Manager

CERTIFICATION

I hereby certify that I have examined the facility, and being familiar with the provisions of 40 CFR part 112, attest that this SPCC Plan has been prepared in accordance with good engineering practices. The following is a sample SPCC Plan for a bulk oil storage facility (Note: other requirements apply to oil production, drilling, and workover facilities). This fictional sample is intended to serve as an example for facilities that are required to prepare an SPCC Plan. Individual facilities are different so each SPCC Plan will be different, and the level of detail in each Plan will be based on the design and size of the facility. A site diagram or diagrams which illustrate the design and organization of a facility (e.g., drainage patterns, locations of spill equipment, etc.) should be included. In this example, the requirements for the SPCC Plan found in 40 CFR 112.7 are enclosed in a box. Sample language for the example facility described as the Neverspill Oil Corporation follows the regulatory citations.

NOTICE

The statements in this document are intended solely as guidance. This document is not
intended and cannot be relied upon to create rights, substantive or procedural, enforceable by any party in litigation with the United States.

1. FACILITY OWNER and OPERATOR:
A. Facility Owner, Address, and Telephone
B. Facility Operator, Address, and Telephone

2. FACILITY CONTACT(s)

3. FACILITY DESCRIPTION
A. Facility Operations
B. Facility Storage
C. Drainage Pathway and Distance to Navigable Waters

4. SPILL HISTORY

5. POTENTIAL SPILL PREDICTIONS, VOLUMES, RATES, AND CONTROL

6. PREVENTION MEASURES PROVIDED
A. Drainage Control
B. Bulk Storage Tanks/Secondary Containment
C. Facility Transfer Operations
D. Facility Tank Car and Truck Loading/Unloading Operations
E. Inspections/Record Keeping
F. Site Security
G. Personnel Training and Spill Prevention Procedures
H. Spill Control Equipment
I. Emergency Contacts

FIGURES

FIGURE 1 FACILITY LAYOUT AND SURFACE DRAINAGE DIAGRAM

APPENDICES

1 SECONDARY CONTAINMENT CALCULATIONS FOR DIKED STORAGE

AREAS
2 DRAINAGE DISCHARGE REPORT FORM
3 FUEL TANK INSPECTION REPORT
4 WEEKLY FACILITY INSPECTION REPORT AND CHECKLIST
5 CERTIFICATION OF THE APPLICABILITY OF THE SUBSTANTIAL HARM CRITERIA CHECKLIST
6 SPCC PLAN CHECKLIST FOR BULK OIL STORAGE FACILITIES 7 SAMPLE CONTAINMENT VOLUME CALCULATIONS

1. FACILITY OWNER and OPERATOR:

2. FACILITY CONTACT(s):

3. FACILITY DESCRIPTION:

Note: The background information in this section is not required by 40 CFR part 112. However, it is recommended that facility background information be provided.

A. Facility Operations:

In this section describe your facility’s day-to-day operations, including hours of operation, personnel, and operational history. In your description include a discussion of the modes of transportation used for receiving products and raw materials (e.g., pipeline, railcar, tanker truck).

B. Facility Storage:

In this section describe all types of oil product storage at your facility including oil products stored in aboveground storage tanks (ASTs), underground storage tanks (USTs), oil-filled electrical equipment (e.g., circuit breakers, transformers), spill tanks, oil/water separators, vapor recovery units portable tanks, drum storage, and trucks which hold oil product and are parked on site.

C. Drainage Pathway and Distance to Navigable Waters

This section should describe the facility’s proximity to bays, rivers, streams (perennial or intermittent), creeks, ditches, flood control channels, storm drains, and other waterways. Hydrological systems should be diagramed or described.

4. SPILL HISTORY [112.7(a)]:

112.7(a) A facility which has experienced one or more spill events within twelve months prior to the effective date of this part should include a written description of each such spill, corrective action taken and plans for preventing recurrence.

Note: Include type and amount of oil spilled, location, date and time of spill(s), watercourses affected (if any), physical damages, cost of damages, cost of cleanup, cause of spill or discharge, and corrective action taken.

5. POTENTIAL SPILL PREDICTIONS, VOLUMES, RATES, AND CONTROL [112.7(b)]:

112.7(b) Where experience indicates a reasonable potential for equipment failure (such as tank overflow, rupture, or leakage), the plan should include 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 major type of failure.

Note: Types of failures to consider include tank (aboveground and underground) overflow, rupture or leakage, pipe failure, wastewater treatment facility failure and spills during transfer operations at the rack and/or dock or tank truck parking areas. The direction a spill would flow can be predicted by drainage patterns, the location of storm or sewer drains, and secondary containment; these predictions should be performed or verified by a Professional Engineer. The rate of flow will depend upon the size and location of the failure and the equipment involved. The total quantity of oil which could be discharged from the facility should be based on a worst case situation and the time it would take to respond to a spill (e.g., shutting off a pump or closing a valve).

6. PREVENTION MEASURES PROVIDED:

Drainage Control Diversionary Structures and Containment [112.7(c)]
112.7(c) Appropriate containment and/or diversionary structures or equipment to prevent discharged oil from reaching a navigable water course should be provided. One of the following preventive systems or its equivalent should be used as a minimum:
(1) Onshore facilities:
(i) Dikes, berms or retaining walls sufficiently impervious to contain spilled oil;
(ii) Curbing;
(iii) Culverting, gutters or other drainage systems;
(iv) Weirs, booms or other barriers;
(v) Spill diversion ponds;
(vi) Retention ponds;
(vii) Sorbent materials.
(2) Offshore facilities:
(i) Curbing, drip pans;
(ii) Sumps and collection systems.

A. Drainage Control [112.7(e)(1)(i-v)]:

(i) Drainage from diked storage areas:
112.7(e) (1) Facility drainage (onshore); (excluding production facilities). (i) Drainage from diked storage areas should be restrained by valves or other positive means to prevent a spill or other excessive leakage of oil into the drainage system or in plant effluent treatment system, except where plant systems are designed to handle such leakage. Diked areas may be emptied by pumps or ejectors; however, these should be manually activated and the condition of the accumulation should be examined before starting to be sure no oil will be discharged into the water.

Note: This section should describe drainage in areas of the facility which have localized secondary containment. Localized containment is specifically designed to retain drainage in operating areas of a facility (e.g., AST farm, truck loading/unloading rack, pipeline areas.)

(ii) Valves used on diked area storage:
112.7(e) (1) Facility drainage (onshore); (excluding production facilities). (ii) Flapper-type drain valves should not be used to drain diked areas. Valves used for the drainage of diked areas should, as far as practical, be of manual, open-and-closed design. When plant drainage drains directly into water courses and not into wastewater treatment plants, retained storm water should be inspected as provided in paragraphs (e)(2)(iii) (B), (C) and (D) of this section before drainage.

(iii) Plant drainage systems from undiked areas:
112.7(e) (1) Facility drainage (onshore); (excluding production facilities). (iii) Plant drainage systems from undiked areas should, if possible, flow into ponds, lagoons or catchment basins, designed to retain oil or return it to the facility. Catchment basins should not be located in areas subject to periodic flooding.

Note: This section should describe drainage in areas of the facility that do not have localized containment (e.g., area drains to a retention pond). Facilities must ensure that such systems are designed in accordance with good engineering practices.

(iv) Final discharge of drainage:
112.7(e) (1) Facility drainage (onshore); (excluding production facilities). (iv) If plant drainage is not engineered as above, the final discharge of all in plant ditches should be equipped with a diversion system that could, in the event of an uncontrolled spill, return the oil to the plant.

(v) Facility Drainage Systems and Equipment:
112.7(e) (1) Facility drainage (onshore); (excluding production facilities). (v) Where drainage waters are treated in more than one treatment unit, natural hydraulic flow should be used. If pump transfer is needed, two ‘‘lift’’ pumps should be provided, and at least one of the pumps should be permanently installed when such treatment is continuous. In any event, whatever techniques are used facility drainage systems should be adequately engineered to prevent oil from reaching navigable waters in the event of equipment failure or human error at the facility.

Note: Facilities that use a wastewater treatment system (a system with two or more treatment units) for treating drainage must have a backup system in place should the system fail. In accordance with the Professional Engineer certification, the water collection and treatment system must be designed utilizing good engineering practices. The facility must describe the water collection and treatment system and its redundancies, including the use of oil/water separators.

B. Bulk Storage Tanks/Secondary Containment [112.7(e)(2)(i-xi)]:

(i) Tank compatibility with its contents:
112.7(e) (2) Bulk storage tanks (onshore); (excluding production facilities). (i) No tank should be used 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, etc.

Note: Describe in detail the construction of all aboveground storage tanks and their compatibility with the liquids that they hold. Identify which standards (e.g., API standards) of construction have been followed and features of the individual tanks (e.g., double bottoms, coatings).

(ii) Diked area construction and containment volume for storage tanks:
112.7(e) (2) Bulk storage tanks (onshore); (excluding production facilities). (ii) All bulk storage tank installations should be constructed so that a secondary means of containment is provided for the entire contents of the largest single tank plus sufficient freeboard to allow for precipitation. Diked areas should be sufficiently impervious to contain spilled oil. Dikes, containment curbs, and pits are commonly employed for this purpose, but they may not always be appropriate. An alternative system could consist of a complete drainage trench enclosure arranged so that a spill could terminate and be safely confined in an in plant catchment basin or holding pond.

Note: Precipitation freeboard should be based on regional rainfall patterns.

112.7(e) (2) Bulk storage tanks (onshore); (excluding production facilities). (iii) Drainage of rainwater from the diked area into a storm drain or an effluent discharge that empties into an open water course, lake, or pond, and bypassing the in plant treatment system may be acceptable if:
(A) The bypass valve is normally sealed closed.
(B) Inspection of the run off rain water ensures compliance with applicable water quality standards and will not cause a harmful discharge as defined in 40 CFR part 110.
(C) The bypass valve is opened and resealed following drainage under responsible supervision.
(D) Adequate records are kept of such events.

Note: This section should include a detailed discussion of the inspection and drainage procedures used for diked areas and how drainage discharge is documented (e.g., checklist noting the appearance of the water, time of valve opening, time of valve closing, signature of inspector, etc.). This section should also include a discussion of an alternate method of drainage to be employed if an oil sheen or oil accumulation is observed.

(iii) Diked area, inspection and drainage of rainwater:

(iv) Corrosion protection of buried metallic storage tanks:
112.7(e) (2) Bulk storage tanks (onshore); (excluding production facilities). (iv) Buried metallic storage tanks represent a potential for undetected spills. A new buried installation should be protected from corrosion by coatings, cathodic protection or other effective methods compatible with local soil conditions. Such buried tanks should at least be subjected to regular pressure testing.

Note: Underground storage tanks for purposes of SPCC must be completely buried, unlike “underground storage tanks” in EPA’s UST program, which may be partially buried.

(v) Corrosion protection of partially buried metallic tanks:
112.7(e) (2) Bulk storage tanks (onshore); (excluding production facilities). (v) Partially buried metallic tanks for the storage of oil should be avoided, unless the buried section of the shell is adequately coated, since partial burial in damp earth can cause rapid corrosion of metallic surfaces, especially at the earth/air interface.

(vi) Aboveground tank periodic integrity testing:
112.7(e) (2) Bulk storage tanks (onshore); (excluding production facilities). (vi) Aboveground tanks should be subject to periodic integrity testing, taking into account tank design (floating roof, etc.) and using such techniques as hydrostatic testing, visual inspection or a system of nondestructive shell thickness testing. Comparison records should be kept where appropriate, and tank supports and foundations should be included in these inspections. In addition, the outside of the tank should frequently be observed by operating personnel for signs of deterioration, leaks which might cause a spill, or accumulation of oil inside diked areas.

(vii) Control of leakage through internal heating coils:
112.7(e) (2) Bulk storage tanks (onshore); (excluding production facilities). (vii) To control leakage through defective internal heating coils, the following factors should be considered and applied, as appropriate.
(A) The steam return or exhaust lines from internal heating coils which discharge into an open water course should be monitored for contamination, or passed through a settling tank, skimmer, or other separation or retention system.
(B) The feasibility of installing an external heating system should also be considered.

(viii) Tank installation fail-safe engineered:
112.7(e) (2) Bulk storage tanks (onshore). (viii) New and old tank installations should, as far as practical, be fail-safe engineered or updated into a fail-safe engineered installation to avoid spills. Consideration should be given to providing one or more of the following devices:
(A) High liquid level alarms with an audible or visual signal at a constantly manned operation or surveillance station; in smaller plants an audible air vent may suffice.
(B) Considering size and complexity of the facility, high liquid level pump cutoff devices set to stop flow at a predetermined tank content level.
(C) Direct audible or code signal communication between the tank gauger and the pumping station.
(D) A fast response system for determining the liquid level of each bulk storage tank such as digital computers, telepulse, or direct vision gauges or their equivalent.
(E) Liquid level sensing devices should be regularly tested to insure proper operation.

Note: In order to provide adequate fail-safe engineering, redundancy should be employed. Inventory control and “sticking” are not adequate methods unless a second form of overfill prevention is utilized.

(ix) Observation of disposal facilities for effluent discharge:
112.7(e) (2) Bulk storage tanks (onshore); (excluding production facilities). (ix) Plant effluents which are discharged into navigable waters should have disposal facilities observed frequently enough to detect possible system upsets that could cause an oil spill event. Note: Facilities must indicate what type of backup system is used in the event of equipment malfunction.

(A) High liquid level alarms with an audible or visual signal at a constantly manned operation or surveillance station; in smaller plants an audible air vent may suffice.
(B) Considering size and complexity of the facility, high liquid level pump cutoff devices set to stop flow at a predetermined tank content level.
(C) Direct audible or code signal communication between the tank gauger and the pumping station.

(D) A fast response system for determining the liquid level of each bulk storage tank such as digital computers, telepulse, or direct vision gauges or their equivalent.
(E) Liquid level sensing devices should be regularly tested to insure proper operation.

Note: Facilities must indicate what type of backup system is used in the event of equipment malfunction.

(x) Visible oil leak corrections from tank seams and gaskets:
112.7(e) (2) Bulk storage tanks (onshore); (excluding production facilities). (x) Visible oil leaks which result in a loss of oil from tank seams, gaskets, rivets and bolts sufficiently large to cause the accumulation of oil in diked areas should be promptly corrected.

(xi) Appropriate position of mobile or portable oil storage tanks:
112.7(e) (2) Bulk storage tanks (onshore); (excluding production facilities). (xi) Mobile or portable oil storage tanks (onshore) should be positioned or located so as to prevent spilled oil from reaching navigable waters. A secondary means of containment, such as dikes or catchment basins, should be furnished for the largest single compartment or tank. These facilities should be located where they will not be subject to periodic flooding or washout.

C. Facility Transfer Operations [112.7(e)(3)(i-v)]:

(i) Buried piping installation protection and examination:
112.7(e) (3) Facility transfer operations, pumping, and in plant process (onshore); (excluding production facilities). (i) Buried piping installations should have a protective wrapping and coating and should be cathodically protected if soil conditions warrant. If a section of buried line is exposed for any reason, it should be carefully examined for deterioration. If corrosion damage is found, additional examination and corrective action should be taken as indicated by the magnitude of the damage.

(ii) Not-in-service and standby service terminal connections:
112.7(e) (3) Facility transfer operations, pumping, and in plant process (onshore); (excluding production facilities). (ii) When a pipeline is not in service, or in standby service for an extended time the terminal connection at the transfer point should be capped or blank-flanged, and marked as to origin.

(iii) Pipe supports design:
112.7(e) (3) Facility transfer operations, pumping, and in plant process (onshore); (excluding production facilities). (iii) Pipe supports should be properly designed to minimize abrasion and corrosion and allow for expansion and contraction.

(iv) Aboveground valve and pipeline examination:
112.7(e) (3) Facility transfer operations, pumping, and in plant process (onshore); (excluding production facilities). (iv) All aboveground valves and pipelines should be subjected to regular examinations by operating personnel at which time 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 should be assessed. In addition, periodic pressure testing may be warranted for piping in areas where facility drainage is such that a failure might lead to a spill event.

(v) Aboveground piping protection from vehicular traffic:
112.7(e) (3) Facility transfer operations, pumping, and in plant process (onshore); (excluding production facilities). (v) Vehicular traffic granted entry into the facility should be warned verbally or by appropriate signs to be sure that the vehicle, because of its size, will not endanger aboveground piping.

Note: Identify how aboveground piping is protected from vehicular traffic (e.g., bumper poles or other barriers, clearance signs).

D. Facility Tank Car and Truck Loading/Unloading Operations [112.7(e)(4)(i-iv)]:

E. Inspections/Record Keeping [112.7(e)(8)]:

112.7(e) (8) Inspections and records. Inspections required by this part should be in accordance with written procedures developed for the facility by the owner or operator. These written procedures and a record of the inspections, signed by the appropriate supervisor or inspector, should be made part of the SPCC Plan and maintained for a period of three years.

Note: Written inspection procedures (e.g., checklist) should be included in the SPCC Plan. Documentation of the inspections can be maintained in a separate location other than the SPCC Plan as long as their location is referenced as a part of the SPCC Plan for three years. All other records pertaining to SPCC (e.g., drainage discharges, tank integrity testing, training records, etc.) must also be maintained for three years.

F. Site Security [112.7(e)(9)(i-v)]:

(i) Fencing:
112.7(e) (9) Security (i) All plants handling, processing, and storing oil should be fully fenced, and entrance gates should be locked and/or guarded when the plant is not in production or is unattended.

(ii) Flow valves locked:
112.7(e) (9) Security (ii) The master flow and drain valves and any other valves that will permit direct outward flow of the tank’s content to the surface should be securely locked in the closed position when in nonoperating or non-standby status.

(iii) Starter controls locked:
112.7(e) (9) Security (iii) The starter control on all oil pumps should be locked in the ‘off’ position or located at a site accessible only to authorized personnel when the pumps are in a nonoperating or nonstandby status.

(iv) Pipeline loading/unloading connections securely capped:
112.7(e) (9) Security (iv) The loading/unloading connections of oil pipelines should be securely capped or blank-flanged when not in service or standby service for an extended time. This security practice should also apply to pipelines that are emptied of liquid content either by draining or by inert gas pressure.

(v) Lighting adequate to detect spills:
112.7(e) (9) Security (v) Facility lighting should be commensurate with the type and location of the facility. Consideration should be given to:
(A) Discovery of spills occurring during hours of darkness, both by operating personnel, if present, and by nonoperating personnel (the general public, local police, etc.) and
(B) prevention of spills occurring through acts of vandalism.

G. Personnel Training and Spill Prevention Procedures [112.7(e)(10)(i-iii)]:

(i) Personnel instructions:
112.7(e) (10) Personnel, training and spill prevention procedures. (i) Owners or operators are responsible for properly instructing their personnel in the operation and maintenance of equipment to prevent the discharges of oil and applicable pollution control laws, rules and regulations.

Note: Describe spill prevention and operation’s training for new hires and refresher training for all personnel.

(ii) Designated person accountable for spill prevention:
112.7(e) (10) Personnel, training and spill prevention procedures.(ii) Each applicable facility should have a designated person who is accountable for oil spill prevention and who reports to line management.

(iii) Spill prevention briefings:
112.7(e) (10) Personnel, training and spill prevention procedures. (iii) Owners or operators should schedule and conduct spill prevention briefings for their operating personnel at intervals frequent enough to assure adequate understanding of the SPCC Plan for that facility. Such briefings should highlight and describe known spill events or failures, malfunctioning components, and recently developed precautionary measures.

H. Spill Control Equipment:

List all spill control equipment stored at your facility (e.g., granular absorbent, empty drums, shovels, brooms, absorbent pads and booms, vacuum truck) for the purposes of meeting the requirements of 112.7(c).

1.1 I. Emergency Contacts

Part 110-Discharge of Oil: 110.10 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
§110.6, immediately notify the National Response Center (NRC) (800-424-8802; in the Washington, DC metropolitan area, 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. (Approved by the Office of Management and Budget under the control number 2050-0046).

Note: In this section include emergency telephone numbers for spill notification (e.g., Federal National Response Center, key facility personnel, and cleanup contractors.)

APPENDIX 3 - FUEL TANK INSPECTION REPORT

Date Location Liquid Level

Tank No. Temp.
Capacity Diameter Height

1. Weather Stripping or Flashing

a. Are all pieces tight against shell?
b. Are any pieces missing or (Photo No. ) require repairs? How many?

2. Hoses & Piping

a. General appearance of hoses
b. Any leaks? If so, explain
c. Aboveground piping free of leaks?

3. Roof Ladder

a. Does ladder appear to roll easily or need repairs?

4. Contamination

a. Is roof free of oil and water? If not, indicate percent coverage of each liquid and depth at worst location on attached drawing.

5. Corrosion Control

a. Note general appearance of paint on shell, roof, ladder and structural members:
b. Is rusting or pitting occurring on any of the above? If yes, explain where and if repairs are needed immediately.
c. Are all insulating flange washers and sleeves in place? If missing, cracked, or broken, explain where and repairs needed:
d. Are all ground and/or anode straps in place? If missing or damaged, indicate location on drawing and

explain repairs needed:

6. Are high-level alarms functioning properly? Tested to verify?

7. Other Observations

a. Note anything that might affect smooth movement of roof and any problem that would allow escape of vapors or air pollution:

8. Show any damaged areas or problem areas (on tanks with floating roof, show location and size of any gaps in seal) on attached drawing.

9. Remote and side gauges working

APPENDIX 4 - WEEKLY FACILITY INSPECTION REPORT AND CHECKLIST

Date: ___________________________________________________
Time: ___________________________________________________
Inspector: ________________________________________________

X=Satisfactory

NA=Not Applicable
0=Repair or Adjustment Required
C=See comment under

Remarks/Recommendations

Drainage ASTs

____ Any noticeable oil sheen on runoff. ____ Tank surfaces checked for signs of leakage. ____ Containment area drainage valves are closed and locked.
____ Tank condition good (no rusting, corrosion, pitting).
____ Oil/water separator systems working properly.
____ Bolts, rivets, or seams are not damaged.
____ Effluent from oil/water separator inspected.
____ Tank foundation intact.
____ No visible oil sheen in containment area.
____ Level gauges and alarms working properly.
____ No standing water in containment area.
____ Vents are not obstructed.
____ Valves, flanges, and gaskets are free from leaks.
____ Containment walls are intact.

Pipelines Truck Loading/Unloading Area

____ No signs of corrosion damage to pipelines or supports. ____ No standing water in rack area.
____ Buried pipelines are not exposed.
____ Warning signs posted.
____ Out-of-service pipes capped.
____ No leaks in hoses.
____ Signs/barriers to protect pipelines from vehicles are in place. ____ Drip pans not overflowing.
____ No leaks at valves, flanged, or other fittings.
____ Catch basins free of contamination.
____ Containment curbing or trenches intact.
____ Connections are capped or blank-flanged.

Security Training

____ Fence and gates intact.
____ Spill prevention briefing held.
____ Gates have locks.
____ Training records are in order.
____ ASTs locked when not in use.
____ Starter controls for pumps locked when not in use. ____ Lighting is working properly.

Remarks/Recommendations:

APPENDIX 6 - SPCC PLAN CHECKLIST FOR BULK OIL STORAGE FACILITIES

I. Operator and Owner Addresses and Phone Nos.

II. Day-to-day Operations and Facility Background

III. Receiving Water/Probable Flow Paths (e.g., facility storm drain, street storm drain, WWTP outfall)

IV. Copy of SPCC Plan/Site Diagrams

__ Certification of engineer: 112.3 (d).
__ Reviewed within past three years: 112.5(b).
__ Full approval of appropriate level management: 112.7. __ Spill history: 112.7(a)
__ Spill predictions: 112.7(b)
__ Diversionary structures and conainment: 112.7(c)

V. SPCC Measures

112.7(e)(1) Facility drainage:

____i) Dike drainage via valves or manually controlled pumps.
____ii) No flapper-type drain valves on diked areas. Dike drain valves manual control. ____iii) Undiked area drains to catch basin.
____iv) If no drain prep as above. Diversion system to return oil.
____v) If drainage water not moved by gravity flow, then redundant lift pump setup.

112.7(e)(2) Bulk storage tanks:

____i) Material and construction compatible with contents.
____ii) Secondary containment for largest tank + precipitation, and
____ dikes sufficiently impervious to spilled oil.
____ or trench enclosure draining to catch basin. iii) Rainwater drainage (into a storm drain or water course) bypassing in plant treatment okay if:
____ bypass valve normally sealed closed, and
____ inspection and compliance with water quality standards, and
____ valve opened under responsible supervision, and
____ records kept of drainage events.
____iv) Buried tanks protected against corrosion/regular pressure testing.
____v) Partially buried tanks protected against corrosion.
____vi) Surface tanks integrity tested via hydrostatic, visual inspection, or nondestructive shell thickness methods. Construction of tanks base adequate.
____vii) Internal heating coils are closed loop or treated and monitored.
____viii) Fail-safe engineering on all tanks, new and old, via high liquid level alarms or high liquid level pump cutoff devices, or audible/code warning, and
____ regular testing of liquid level sensors.
____ix) Water discharge facilities inspected regularly (NPDES).
____x) Visible leaks on tanks and piping corrected (Protocol).
____xi) Secondary containment for largest portable storage tank.
____ Portable tank area free from periodic flooding or washout.

112.7(e)(3) Facility transfer operations:

____i) Buried piping protected against corrosion.
____ii) Out-of-service pipes capped with origin marked.
____iii) Pipe supports minimize abrasion, corrosion, sagging.
____iv) Regular inspection of surface pipe and valves.
____ Regular pressure testing for pipes with no secondary containment.
____v) Signs to warn vehicles about piping.

112.7(e)(4) Facility loading/unloading rack:

____i) Follow DOT procedures for loading/unloading tank cars and tank trucks.
____ii) Secondary containment for largest vehicle compartment (or quick drainage system).
____iii) Prevention of early vehicle departure via warning signs, physical barriers, or warning light.
____iv) Vehicles examined for leakage at all outlets prior to departure.

112.7(e)(8) Inspections and records:

____ Written procedures records kept for three years of inspections and,
____ Records (inspections, discharges, training, briefings) kept for three years.

112.7(e)(9) Security:

____(i) Fully fenced.
____ Gates locked when plant unattended.
____(ii) Master flow and drain valves of tanks locked closed.
____(iii) Starter control locked “off” or located where only the authorized have access.
____(iv) Out-of-service pipelines capped or blank-flanged.
____(v) Lighting adequate for night spill detection and deterring vandals.

112.7(e)(10) Personnel, training and spill prevention procedures:

____(i) Personnel instructed in equipment operation and oil regulations.
____(ii) One person accountable for spill prevention.
____(iii) Owner/operator schedules regular briefings.

____ 112.20(e) Applicability of Substantial Harm Criteria Checklist Completed.

Sample Spill Prevention Control and Countermeasure Plan (SPCC)

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