A non-transportation related onshore or off shore facility engaged in:

• Drilling,
• Producing
• Gathering
• Storing
• Processing
• Refining
• Transferring
• Distributing
• Using, or
• Consuming of oil and oil products.

• Underground Petroleum Storage Capacity > 42, 000 gallons, aggregate
• Above Ground Storage Capacity > 1,320 gallons, aggregate
• ONLY Containers of > 55 gallons capacity are included in capacity calculation.
• A bunkered tank is subject to the rules. A bunkered tank is one that is constructed by cutting the earth or placing in the ground and recovering of the container that breaks the natural grade.

• Underground tanks and piping subject to Part 280 rules.
• Containers < 55 gallons
• A facility that could not discharge oil by the nature of its location and physical setting.
• Any facility or part of a facility used exclusively for wastewater treatment.

• Oil Filled Electrical Equipment
• Oil Filled Operating Equipment
• Oil Filled Manufacturing Equipment

OIL FILLED OPERATING and ELECTRICAL Equipment can becomes subject to the SPCC requirements if the facility:

• It is already subject to the SPCC requirements because of bulk storage quantity
• Its is subject to the SPCC because of its location

• Building
• Structure
• Installation
• Equipment
• Pipe
• Pipeline

Used in drilling operations, oil production, oil gathering, oil processing, oil transfer, oil distribution, and waste oil treatment, or in which oil is used as described in Appendix A.

 

• Professional Engineer: document by written statement any technical amendment.
• Owner or Operator: Written statement: "I have completed review of the SPCC Plan for (name of facility) on (date) and will (will not) amend the Plan as a result."

• Petroleum in an form
• Crude oil
• Fuel oil
• Mineral oil
• Oil sludge
• Oil refuse
• Refined products.

Facilities in operation, on or before August 16, 2002.

• Review and amend if necessary by August 17, 2004.
• Implement the amendments NLT February 16, 2005.
• Must be reviewed every 5 years thereafter.

Facilities that become operational after August 18, 2003

• Prepare and Implement the SPCC before becoming operational.

• At lease every FIVE (5) Years
• Implement any amendment within 6 months of the review.

• As a result of review and evaluation, the SPCC must be amended to "include more effective prevention technology if the technology has been field proven …, and will significantly reduce the likelihood of a discharge."

• Cross reference section in SPCC Plan if order of included provisions is different than listed in the rule.
• Facilities not yet fully operational must be discussed in the Plan.
• Discussion of conformance with the requirements of §112.
• Identify secondary containment and how it conforms to the requirements.
• Where the Plan is not in conformance, the nonconformance must be discussed and the alternatives provided.
• Describe the facility in the SPCC – Include a facility diagram.
• Diagram must include all above ground, partially buried and buried tanks., and their contents.
• Diagram must include transfer stations and connecting piping.
• Type of oil in each container and the capacity.
• Discharge prevention measures including routine handling procedures.
• Discharge or drainage controls
• Countermeasures for discharge discovery and clean up.
• Disposal methods for recovered materials.
• Contact list and phone numbers.
• Information to be given when making a report to the Agency of a spill.
• Organize the plan for readily usable.
• Where experience indicates a reasonable potential for equipment failure: prediction of direction, rate of flow, and total quantity of oil which could be discharged.
• Provide appropriate containment or diversionary structures.
• Minimum list of containment structures. On shore facilities.
• Dikes or berms or retaining walls
• Curbing
• Culverting, gutters or other drainage systems
• Weirs, booms, or other barriers
• Spill diversion ponds
• Retention ponds
• Sorbent materials
• Minimum list of containment structures. Off shore facilities.
• Curbing
• Drip pans
• Sumps and collections systems
• If it is determined that minimums are not practical, a clear explanation of why they can be used must be included.
• An oil spill contingency plan following the provisions of Part 109
• Designate an accountable persons at the facility for discharge prevention.

• Train, at a minimum, the oil handling personnel on the rules and contents of the plan.
• Discharge prevention briefings for oil handling personnel at least once per year.

• Fully fence each facility handling, processing, or storing oil.
• Lock or guard each entrance when not in operation.
• Security of drain valves.
• Lock all transfer pumps in the off position when not in use.
• Cap or blank loading and unloading connections.
• Provide facility lighting to: assist in discovery of leaks and discourage vandalism.

• Where the racks does not discharge into a catchment basin or treatment facility, design a containment facility to hold maximum contents of truck or RR car tank.
• Provide a method to prevent the vehicle from leaving before disconnecting from the rack.
• Prior to filling and departure inspect the vehicle for leaks.

• Evaluate repairs of containers for brittle fracture as a result of repair.

• Discuss applicability of state rules.
• Identify more stringent state rules, regulations or guidelines.

FACILITY DRAINAGE – Required for Petroleum and Non-petroleum oils except animal and plant fats and oils.

• Restrain drainage from all containment areas.
• Drainage to stormwater channels or surface water can only be done if monitored, and the manual valve is opened and closed/sealed at the end of the drain event.
• Keep adequate records of draining events. Records already required by stormwater permits are satisfactory.
• Drainage Pumps cannot be remotely started.
• Manual valves must be used to drain dikes. Flapper types of valves are prohibited.
• Only uncontaminated water may be drained from dikes.
• Design facility drainage systems for piping, truck transfer and run-off to flow catchment basins, ponds or lagoons designed to retain oil.
• If drainage does not go to control structures, then the final discharge from all ditches must be equipped with a diversion system that would retain oil from an uncontrolled discharge.
• Where drainage treatment is installed that uses a pump, there must be a standby pump designed to start if the first pump fails.
• Drainage systems may use any method, but must be engineered to prevent a discharge of oil in the event of either equipment failure or human error.

• Test above ground containers on a regular basis. The frequency is not specified.
• Records of testing must be kept. Visual inspections are not sufficient. Other technical testing of tank integrity must also be done.
• Foundations and structures of the tanks must also be inspected. Records must be kept.

• Monitor steam oil returns for oil contamination.
• Exhaust lines through a control device that allows for separation and retention of oil.

• Corrosion protection by cathodic or coating is required if the tank was installed after January 10, 1974.
• Partially buried metallic tanks must have cathodic or coating protection for the buried portion.

• Required for each container installation subject to this standard.
• Update each installation using good engineering practice to avoid discharges , and provide at least one of the following:
• High Level Alarms with an audible or visual signal at a constantly attended operation station. Small facilities may use an audible air vent.
• High level shut off for pumps at a specified container volume.
• Direct audible or code signal communication between the container gauger and the pumping station.
• A fast response system for determining liquid level of each bulk storage container. Additional monitoring requirements for persons to be present at the telecommunication or computer station, if this alternative is selected.
• Must regularly test liquid level sensing devices to ensure proper function. Regularly is not specified.

• If done after August 16, 2002, the piping must be wrapped and protective coated.
• Where subject to Chapter 280, install cathodic protection.

• If underground piping is uncovered, it must be inspected for corrosion.
• If corrosion is detected, additional examination and corrective action is required.
• Cap or blank off piping that is out of service or placed into extended standby status.
• Design all pipe support to minimize abrasion and corrosion, allow for expansion and contraction.
• Regularly inspect all above ground valves, piping and appurtenances. Regularly is not defined. During such inspections, assessment of the following should be included:
• Flange joints
• Expansion joints
• Valve glands
• Valve bodies
• Catch pans
• Pipeline supports
• Locking valves
• Condition of metal surfaces
• All underground piping must be leak tested at the time or Installation, Modification, Construction, Relocation or Replacement.
• Post Warnings for vehicles to prevent damage to overhead and underground piping.

• The requirements are generally the same as on-shore facilities.

• The requirements are generally the same as for on-shore petroleum oil facilities.