| (e) BMP and Minimum Requirements. For any new project,
and any associated emission control equipment registered under this
section, paragraphs (1) - (5) of this subsection shall be met as applicable.
These requirements are not applicable to existing, unchanging facilities.
Equipment design and control device requirements listed in paragraphs
(6) - (12) of this subsection only apply to those that are chosen
by the operator to meet the limitations of this section.
(1) All facilities which have the potential to emit
air contaminants must be maintained in good working order and operated
properly during facility operations. Each operator shall establish
and maintain a program to replace, repair, and/or maintain facilities
to keep them in good working order. The minimum requirements of this
program shall include:
(A) Compliance with manufacturer's specifications and
recommended programs applicable to equipment performance and effect
on emissions, or alternatively, an owner or operator developed maintenance
plan for such equipment that is consistent with good air pollution
control practices;
(B) cleaning and routine inspection of all equipment;
and
(C) replacement and repair of equipment on schedules
which prevent equipment failures and maintain performance.
(2) Any facility shall be operated at least 50 feet
from any property line or receptor (whichever is closer to the facility).
This distance limitation does not apply to the following:
(A) any fugitive components that are used for isolation
and/or safety purposes may be located at 1/2 of the width of any applicable
easement;
(B) any facility at a location for which the distance
requirements were satisfied at the time this section is claimed, registered,
or certified (provided that the authorization was maintained) regardless
of whether a receptor is subsequently built or put to use less than
50 feet from any OGS facility; or
(C) existing facilities which are located less than
50 feet from a property line or receptor when constructed and previously
authorized. If modified or replaced the operator shall consider, to
the extent that good engineering practice will permit, moving these
facilities to meet the 50-foot requirement. Replacement facilities
must meet all other requirements of this section.
(3) Engines and turbines shall meet the emission and
performance standards listed in Table 6 in subsection (m) of this
section and the following requirements:
(A) liquid fueled engines used for back-up power generation
and periodic power needs at the OGS are authorized if the fuel has
no more than 0.05% sulfur and the engine is operated less than 876
hours per rolling 12-month period;
(B) engines and turbines used for electric generation
more than 876 hours per rolling 12-month period are authorized if
no reliable electric service is readily available and Table 6 in subsection
(m) of this section is met. In all other circumstances, electric generators
must meet the technical requirements of the Air Quality Standard Permit
for Electric Generating Unit (EGU) (not including the EGU standard
permit registration requirements) and the emissions shall be included
in the registration under this section;
(C) all applicable requirements of Chapter 117 of this
title (relating to Control of Air Pollution from Nitrogen Compounds);
(D) all applicable requirements of 40 CFR Parts 60
and 63; and
(E) compression ignition engines that are rated less
than 225 kilowatts (300 hp) and emit less than or equal to the emission
tier for an equivalent-sized model year 2008 non-road compression
ignition engine located at 40 CFR §89.112, Table 1 are authorized.
(4) Open-topped tanks or ponds containing VOCs or H2S are allowed up to a potential to emit equal
to 1.0 tpy of VOC and 0.1 tpy of H2S.
(5) The following shall apply to all fugitive components
at the site associated with the project:
(A) All components shall be physically inspected quarterly
for leaks.
(B) All components found to be leaking shall be repaired.
Every reasonable effort shall be made to repair a leaking component.
All leaks not repaired immediately shall be tagged or noted in a log.
At manned sites, leaks shall be repaired no later than 30 days after
the leak is found. At unmanned sites, leaks shall be repaired no later
than 60 days after the leak is found. If the repair of a component
would require a unit shutdown, which would create more emissions than
the repair would eliminate, the repair may be delayed until the next
shutdown.
(C) Tank hatches, not designed to be completely sealed,
shall remain closed (but not completely sealed in order to maintain
safe design functionality) except for sampling, gauging, loading,
unloading, or planned maintenance activities.
(D) To the extent that good engineering practices will
permit, new and reworked valves and piping connections shall be located
in a place that is reasonably accessible for leak checking during
plant operation. Underground process pipelines shall contain no buried
valves such that fugitive emission monitoring is rendered impractical.
(6) When leak detection and repair (LDAR) fugitive
monitoring is chosen by the operator, Table 9, in subsection (m) of
this section, shall apply. In addition, all components shall be physically
inspected at least weekly by operating personnel walk-through.
(7) Tanks and vessels that utilize a paint color to
minimize the effects of solar heating (including, but not limited
to, white or aluminum):
(A) to meet this requirement the solar absorptance
should be 0.43 or less, as referenced in Table 7.1 - 6 in Compilation
of Air Pollutant Emission Factors (AP-42);
(B) paint shall be applied according to paint producers
recommended application requirements if provided and in sufficient
quantity as to be considered solar resistant;
(C) paint coatings shall be maintained in good condition
and will not compromise tank integrity. Minimal amounts of rust may
be present not to exceed 10% of the external surface area of the roof
or walls of the tank and in no way may compromise tank integrity.
Additionally, up to 10% of the external surface area of the roof or
walls of the tank or vessel may be painted with other colors to allow
for identification and/or aesthetics;
(D) for tanks and vessels purposefully darkened to
create the process reaction and help condense liquids from being entrained
in the vapor or are in an area whereby a local, state, federal law,
ordinance, or private contract predating this section's effective
date establishes in writing tank and vessel colors other than white,
these requirements do not apply.
(8) All emission estimation methods including but not
limited to computer programs such as GRI-GLYCalc, AmineCalc, E&P
Tanks, and Tanks 4.0, must be used with monitoring data generated
in accordance with Table 8 in subsection (m) of this section where
monitoring is required. All emission estimation methods must also
be used in a way that is consistent with protocols established by
the commission or promulgated in federal regulations (NSPS, NESHAPS).
Where control is relied upon to meet subsection (k) of this section,
control monitoring is required.
(9) Process reboilers, heaters, and furnaces that are
also used for control of waste gas streams:
(A) may claim 50% to 99% destruction efficiency for
VOCs and H2 S depending on the design
and level of monitoring applied. The 90% destruction may be claimed
where the waste gas is delivered to the flame zone or combustion fire
box with basic monitoring as specified in subsection (j) of this section.
Any value greater than 90% and up to 99% destruction efficiency may
be claimed where enhanced monitoring and/or testing are applied as
specified in subsection (j) of this section;
(B) if the waste gas is premixed with the primary fuel
gas and used as the primary fuel in the device through the primary
fuel burners, 99% destruction may be claimed with basic monitoring
as specified in subsection (j) of this section;
(C) in systems where the combustion device is designed
to cycle on and off to maintain the designed heating parameters, and
may not fully utilize the waste gas stream, records of run time and
enhanced monitoring are required to claim any run time beyond 50%.
(10) Vapor recovery Units (VRUs) may claim up to 100%
control. The control efficiency is based on whether it is a mechanical
VRU (mVRU) or a liquid VRU (lVRU). The VRUs must meet the appropriate
design, monitoring, and recordkeeping in Table 7 and Table 8 in subsection
(m) of this section.
(11) Flares used for control of emissions from production,
planned MSS, emergency, or upset events may claim design destruction
efficiency of 98%. 99% may be claimed for destruction of compounds
containing only carbon, hydrogen, and oxygen with no more than three
carbon atoms. All flares must be designed and operated in accordance
with the following:
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