WHAT'S NEW:

No recent state activity has been identified.

AIR EMISSIONS REGULATIONS:

Air Quality Status	All areas are in attainment EPA's Nonattainment Areas
Major Source Threshold	250 tons (100 for listed sources) of any criteria pollutant
Minor Source Permitting Exemption	Emit less than 5 tpy of all criteria pollutants; emergency units smaller than 500 hp.
Minor Source Treatment	Emission limits for opacity, particulate, NOx and SO2
Emergency Generating Limits	PTE based on 500 hours per year

 

DE MINIMIS EXEMPTIONS

Emergency units smaller than 500 hp are exempt from permitting. No state notification is required, but it is strongly recommended.

MINOR SOURCE PERMITTING

A source qualifies for “de minimis facility” status if emissions of each criteria pollutant are less than 5 tons per year; such sources do not require a permit and need only comply with state regulations on control of air toxics. Permit Sources emitting more than 5 tons per year of a criteria pollutant must obtain a minor source permit. Expected emissions for NOx, VOC and CO are likely to be listed and various rules will be applied such as:

• Units >50 MMBtu/hr heat input have a NOx limit of 0.2 lb/MMBtu for gas, 0.3 lb/MMBtu for liquid fuel and 0.7 lb/MMBtu for solid fuel over a two hour average.
• SO2 limits apply to all minor sources and are 0.2 lb/MMBtu for gas, 0.8 lb/MMBtu for liquid fuel and 1.2 lb/MMBtu for solid fuel. This limit can usually be met with low sulfur fuel.
• Particulate limits vary by unit size; a 10 MMBtu/hr unit has a particulate limit of 0.6 lb/MMBtu.
• Opacity is restricted to 20%.

A “permit exempt facility” is one larger than a “de minimis facility” with actual emissions less than 40 tons per year for each criteria pollutant; such facilities are exempt from permit fees and submission of annual emissions inventories.

The state also has a toxics rule that covers 4,000 toxins and individual ambient concentration limits. This rule has its own BACT, however this is generally not a problem for electric generating units.

Units that cannot meet the above limits will be required to install controls. Sources that emit more than 100 tons per year of any criteria pollutant are required to complete a state-level BACT analysis. The cost threshold is $8,000-$10,000 per ton for NOx.

There is a 30-day public comment period for sources with a potential to emit 100 tons per year or greater. The total permitting time is anywhere from 3 months to 1.5 years for a large PSD project.

MAJOR NSR/PSD PERMITTING

A potential to emit 250 tons (100 tons for listed sources) or more of any criteria pollutant triggers PSD.

TREATMENT OF EMERGENCY ENGINES

Emergency engines are treated the same as other units, however the potential to emit calculation is based on 500 hours per year. Emergency units may only operate during emergencies and for maintenance, but typically there are no actual run hour limits.

SITING REQUIREMENTS FOR NON-UTILITY GENERATORS:

An electrical generation facility does not need the permission of the Oklahoma Corporation Commission. However, certain environmental and emissions permits must be obtained from the Oklahoma DEQ.

BUILDING, ZONING AND FIRE CODES:

Building Codes: Oklahoma enforces the 2006 IBC with amendments as a mandatory minimum. [1]

Energy Codes : Oklahoma does not specifically enforce an energy code. Some energy requirements are enforced by the adoption of the 2006 IBC with amendments. [2]

• Oklahoma Energy Office

Fire Codes: Oklahoma enforces the 2006 IFC with amendments as a mandatory minimum. [3]

• State Fire Marshal

Zoning: Zoning and planning happens at the local level. Check with each jurisdiction regarding their zoning codes.

Resources (information may not be as current as provided above)

A general overview of each state’s enacted codes can be found HERE.

The International Code Council Adoption page gives state-by-state adoption status of specific ICC codes, as well as information about code adoption by some municipal governments within that state.

Information about energy codes can be found at the DOE’s Building Codes for Energy Efficiency page or at the Building Codes Assistance Project.

INTERCONNECTION REQUIREMENTS:

Oklahoma does not have statewide interconnection standards. Relevant provisions for Oklahoma utilities are summarized below.

Public Service Company of Oklahoma - a subsidiary of American Electric Power (AEP): AEP has a standard interconnection application form. A lockable disconnecting switch is required. The application fees are $100 for a single phase system up to 25 kW and $500 for all others. If a study is required then additional charges may apply. Most systems have to meet IEEE 1547 technical standards.

Oklahoma Gas and Electric: The application procedure appears quite lengthy. Systems must comply with national safety standards. Protective devices must be installed. There are no system capacity limits listed, insurance requirements, or simplified procedures for smaller systems.

EXIT FEES:

There is no statewide policy on exit fees. No utilities in the state charge exit fees.

UTILITY STANDBY RATES:

Oklahoma does not have a statewide policy on standby rates. Relevant provisions for Oklahoma utilities are summarized below.

Oklahoma Gas & Electric Co - Schedules MS-1, SS-1, and BUS-1: Standby service is charged through a fixed customer fee and low demand and energy charges. Billing demand is based on the higher of the maximum 15 minute demand of the month or 80% of the maximum from the previous 11 months. Rate information is available at: http://www.oge.com/es/bc/customer-rates.asp

Public Service Co of Oklahoma - According to the "Rules and Regulations" customers are not allowed to operate in parallel with the utility or get standby service. Qualifying facilities that are less than 100 kW can interconnect but must go under the net energy billing schedule. Rate information is available at: https://www.psoklahoma.com/CustomerService/RatesAndTariffs/LegalTariffFilings/Oklahoma.aspx.