| (D) For projects which resolve compliance issues and
are the result of a commission or United States Environmental Protection
Agency order.
(8) If the ePermits system is not available for more
than 24 hours or not otherwise accessible, hard copies of notifications,
registrations, or certifications may be submitted by first-class mail.
(9) If emissions increase at an OGS to a level where
it exceeds its current authorization, either through a change in production
or addition of facilities, the site may claim and register its facilities
under the applicable authorization (Level 1 or Level 2 PBR or Standard
Permit) as follows:
(A) Within 90 days from the initial notification of
construction of an oil and gas facility, a registration can update
the authorization mechanism by submitting a revision to the PBR or
an application for a standard permit; and
(B) Within 90 days of the change of production or installation
of additional equipment, a revision to the PBR or an application for
a standard permit has been submitted.
(g) Level 1 Requirements. Total maximum estimated emissions
shall meet the most stringent of the following. All emissions estimates
must be based on representative worst-case operations and planned
MSS activities.
(1) Emissions of any criteria air contaminant shall
not exceed the applicable limits for a major stationary source or
major modification for PSD, NNSR and in Federal Clean Air Act, §112(g), §112(j),
or the definition of major source in §122.10 of this title.
(2) Emissions must meet the limitations established
in subsection (k) of this section.
(3) Maximum emissions are limited to less than the
following after any operator limitations or controls:
Attached Graphic
(h) Level 2 Requirements. If the requirements of Level
1 cannot be met, then the conditions of this subsection must be followed.
Total maximum estimated registered or certified emissions shall meet
the most stringent of the following. All emissions estimates must
be based on representative worst-case operations and planned MSS activities.
(1) Total maximum estimated annual emissions of any
air contaminant shall not exceed the applicable limits for a major
stationary source or major modification for PSD and NNSR as specified
in §116.12 of this title.
(2) Emissions must meet the limitations established
in subsection (k) of this section.
(3) Maximum emissions are limited to less than the
following after any operator limitations or controls:
Attached Graphic
(i) Planned Maintenance, Startups and Shutdowns. For
any facility, group of facilities or site using this section or previous
versions of this section, the following shall apply.
(1) Prior to January 5, 2012, representations and registration
of planned MSS is voluntary, but if represented must meet the applicable
limits of this section. After January 5, 2012, all emissions from
planned MSS activities and facilities must be considered for compliance
with applicable limits of this section. This section may not be used
at a site or for facilities authorized under §116.111 of this
title if planned MSS has already been authorized under that permit.
(2) As specified, releases of air contaminants during,
or as result of, planned MSS must be quantified and meet the emission
limits in this section, as applicable. This analysis must include:
(A) alternate operational scenarios or redirection
of vent streams;
(B) pigging, purging, and blowdowns;
(C) temporary facilities if used for degassing or purging
of tanks, vessels, or other facilities;
(D) degassing or purging of tanks, vessels, or other
facilities; and
(E) management of sludge from pits, ponds, sumps, and
water conveyances.
(3) Other planned MSS activities authorized by this
section are limited to the following. These planned MSS activities
require only recordkeeping of the activity.
(A) Routine engine component maintenance including
filter changes, oxygen sensor replacements, compression checks, overhauls,
lubricant changes, spark plug changes, and emission control system
maintenance.
(B) Boiler refractory replacements and cleanings.
(C) Heater and heat exchanger cleanings.
(D) Turbine hot section swaps.
(E) Pressure relief valve testing, calibration of analytical
equipment; instrumentation/analyzer maintenance; replacement of analyzer
filters and screens.
(4) Engine/compressor startups associated with preventative
system shutdown activities have the option to be authorized as part
of typical operations if:
(A) prior to operation, alternative operating scenarios
to divert gas or liquid streams are registered and certified with
all supporting documentation;
(B) engine/compressor shutdowns shall result in no
greater than 4 lb/hr of natural gas emissions; and
(C) emissions which result from the subsequent compressor
startup activities are controlled to a minimum of 98% efficiency for
VOC and H2S.
(j) Records, sampling, and monitoring. The following
records shall be maintained at a site in written or electronic form
and be readily available to the agency or local air pollution control
program with jurisdiction upon request. All required records must
be kept at the facility site. If the facility normally operates unattended,
records must be maintained at an office within Texas having day-to-day
operational control of the plant site. Other requirements, including
but not limited to, federal recordkeeping or testing requirements,
can be used to demonstrate compliance if the other requirements are
at least as stringent as the associated requirements in the Tables
7 and 8 in subsection (m) of this section. Any documentation that
is already being kept for other purposes will suffice for demonstrating
requirements. If a control or method is not relied upon for emission
reductions, then the associated sampling, monitoring, and records
are not applicable.
(1) Sampling and demonstrations of compliance shall
include the requirements listed in Table 7 in subsection (m) of this
section.
(2) Monitoring and records for demonstrations of compliance
shall include the requirements listed in Table 8 in subsection (m)
of this section.
(k) Emission limits based on impacts evaluation.
(1) All impacts evaluations must be completed on a
contaminant-by-contaminant basis for any net emissions increases resulting
from a project and must meet the following as appropriate:
(A) Compliance with state or federal ambient air standards
shall be demonstrated for nitrogen dioxide (NO2),
SO2, and H2S
at any property-line within 1/4 mile or 1/2 mile of a project under
subsection (g) (Level 1) or subsection (h) (Level 2) of this section,
respectively.
(B) Compliance with hourly ESLs for benzene and annual
ESL for benzene, shall be demonstrated at the nearest receptor within
1/4 mile or 1/2 mile of a project under subsection (g) (Level 1) or
subsection (h) (Level 2) of this section, respectively.
(2) Distance measurements shall be determined using
the following.
(A) For each facility or group of facilities, the shortest
corresponding distance from any emission point, vent, or fugitive
component to the nearest receptor must be used with the appropriate
compliance determination method with the published ESLs as found through
the TCEQ internet Web page.
(B) For each facility or group of facilities, the shortest
corresponding distance from any emission point, vent, or fugitive
component to the nearest property line must be used with the appropriate
compliance determination method with any applicable state or federal
ambient air quality standard.
(3) Impacts evaluations are not required under the
following cases:
(A) If there is no receptor within 1/4 mile of a Level
1 registration, or 1/2 mile of a Level 2 registration, no further
ESL review is required.
(B) If there is no property line within 1/4 mile of
a Level 1 registration, or 1/2 mile of a Level 2 registration, no
further ambient air quality standard review is required.
(C) If the project total emissions are less than any
of the following rates, no additional analysis or demonstration of
the specified air contaminant is required:
Attached Graphic
(4) Evaluation of emissions shall meet the following.
(A) For all evaluations of NOX to
NO2, a conversion factor of 0.20 for
4-stroke rich and lean-burn engines and 0.50 for 2-stroke lean-burn
engines may be used.
Cont'd... |
