[Title 40 CFR 60.102a]
[Code of Federal Regulations (annual edition) - July 1, 2009 Edition]
[Title 40 - PROTECTION OF ENVIRONMENT]
[Chapter I - ENVIRONMENTAL PROTECTION AGENCY (CONTINUED)]
[Subchapter C - AIR PROGRAMS (CONTINUED)]
[Part 60 - STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES--]
[Subpart Ja - Standards of Performance for Petroleum Refineries for Which]
[Sec. 60.102a - Emissions limitations.]
[From the U.S. Government Printing Office]


40PROTECTION OF ENVIRONMENT62009-07-012009-07-01false60.102aSec. 60.102aPROTECTION OF ENVIRONMENTENVIRONMENTAL PROTECTION AGENCY (CONTINUED)AIR PROGRAMS (CONTINUED)STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES--Standards of Performance for Petroleum Refineries for Which
Sec. 60.102a  Emissions limitations.

    (a) Each owner or operator that is subject to the requirements of 
this subpart shall comply with the emissions limitations in paragraphs 
(b) through (h) of this section on and after the date on which the 
initial performance test, required by Sec. 60.8, is completed, but not 
later than 60 days after achieving the maximum production rate at which 
the affected facility will be operated, or 180 days after initial 
startup, whichever comes first.
    (b) An owner or operator subject to the provisions of this subpart 
shall not discharge or cause the discharge into the atmosphere from any 
FCCU or FCU:
    (1) Particulate matter (PM) in excess of the limits in paragraphs 
(b)(1)(i), (ii), or (iii) of this section.
    (i) 1.0 kilogram per Megagram (kg/Mg)(1 pound (lb) per 1,000 lb) 
coke burn-off or, if a PM continuous emission monitoring system (CEMS) 
is used, 0.040 grain per dry standard cubic feet (gr/dscf) corrected to 
0 percent excess air for each modified or reconstructed FCCU.
    (ii) 0.5 gram per kilogram (g/kg) coke burn-off (0.5 lb PM/1,000 lb 
coke burn-off) or, if a PM CEMS is used, 0.020 gr/dscf corrected to 0 
percent excess air for each newly constructed FCCU.
    (iii) 1.0 kg/Mg (1 lb/1,000 lb) coke burn-off; or if a PM CEMS is 
used, 0.040 grain per dry standard cubic feet (gr/dscf) corrected to 0 
percent excess air for each affected FCU.
    (2) Nitrogen oxides (NOX) in excess of 80 parts per 
million by volume (ppmv), dry basis corrected to 0 percent excess air, 
on a 7-day rolling average basis.
    (3) Sulfur dioxide (SO2) in excess of 50 ppmv dry basis 
corrected to 0 percent excess air, on a 7-day rolling average basis and 
25 ppmv, dry basis corrected to 0 percent excess air, on a 365-day 
rolling average basis.
    (4) Carbon monoxide (CO) in excess of 500 ppmv, dry basis corrected 
to 0 percent excess air, on an hourly average basis.
    (c) The owner or operator of a FCCU or FCU that uses a continuous 
parameter monitoring system (CPMS) according to Sec. 60.105a(b)(1) 
shall comply with the applicable control device parameter operating 
limit in paragraph (c)(1) or (2) of this section.
    (1) If the FCCU or FCU is controlled using an electrostatic 
precipitator:
    (i) The 3-hour rolling average total power and secondary current to 
the entire system must not fall below the level established during the 
most recent performance test; and
    (ii) The daily average exhaust coke burn-off rate must not exceed 
the level established during the most recent performance test.
    (2) If the FCCU or FCU is controlled using a wet scrubber:
    (i) The 3-hour rolling average pressure drop must not fall below the 
level established during the most recent performance test; and
    (ii) The 3-hour rolling average liquid-to-gas ratio must not fall 
below the level established during the most recent performance test.
    (d) If an FCCU or FCU uses a continuous opacity monitoring system 
(COMS) according to the alternative monitoring option in Sec. 
60.105a(e), the 3-hour rolling average opacity of emissions from the 
FCCU or FCU as measured by the COMS must not exceed the site-specific 
opacity limit established during the most recent performance test.
    (e) The owner or operator of a FCCU or FCU that is exempted from the 
requirement for a CO continuous emissions monitoring system under

[[Page 333]]

Sec. 60.105a(h)(3) shall comply with the parameter operating limits in 
paragraph (e)(1) or (2) of this section.
    (1) For a FCCU or FCU with no post-combustion control device:
    (i) The hourly average temperature of the exhaust gases exiting the 
FCCU or FCU must not fall below the level established during the most 
recent performance test.
    (ii) The hourly average oxygen (O2) concentration of the 
exhaust gases exiting the FCCU or FCU must not fall below the level 
established during the most recent performance test.
    (2) For a FCCU or FCU with a post-combustion control device:
    (i) The hourly average temperature of the exhaust gas vent stream 
exiting the control device must not fall below the level established 
during the most recent performance test.
    (ii) The hourly average O2 concentration of the exhaust 
gas vent stream exiting the control device must not fall below the level 
established during the most recent performance test.
    (f) Except as provided in paragraph (f)(3), each owner or operator 
of an affected sulfur recovery plant shall comply with the applicable 
emission limits in paragraphs (f)(1) or (2) of this section.
    (1) For a sulfur recovery plant with a capacity greater than 20 long 
tons per day (LTD):
    (i) For a sulfur recovery plant with an oxidation control system or 
a reduction control system followed by incineration, the owner or 
operator shall not discharge or cause the discharge of any gases into 
the atmosphere in excess of 250 ppm by volume (dry basis) of sulfur 
dioxide (SO2) at zero percent excess air. If the sulfur 
recovery plant consists of multiple process trains or release points the 
owner or operator shall comply with the 250 ppmv limit for each process 
train or release point or comply with a flow rate weighted average of 
250 ppmv for all release points from the sulfur recovery plant; or
    (ii) For sulfur recovery plant with a reduction control system not 
followed by incineration, the owner or operator shall not discharge or 
cause the discharge of any gases into the atmosphere in excess of 300 
ppm by volume of reduced sulfur compounds and 10 ppm by volume of 
hydrogen sulfide (HS2), each calculated as ppm SO2 
by volume (dry basis) at zero percent excess air; or
    (iii) For systems using oxygen enrichment, the owner or operator 
shall calculate the applicable emission limit using Equation 1 of this 
section:
[GRAPHIC] [TIFF OMITTED] TR24JN08.000

Where:

ELS = Emission rate of SO2 for large sulfur 
recovery plant, ppmv;
k1 = Constant factor for emission limit conversion: 
k1 = 1 for converting to SO2 limit and 
k1 = 1.2 for converting to the reduced sulfur compounds 
limit; and
%O2 = O2 concentration to the SRP, percent by 
volume (dry basis).

    (2) For a sulfur recovery plant with a capacity of 20 LTD or less:
    (i) For a sulfur recovery plant with an oxidation control system or 
a reduction control system followed by incineration, the owner or 
operator shall not discharge or cause the discharge of any gases into 
the atmosphere in excess of 2,500 ppm by volume (dry basis) of 
SO2 at zero percent excess air. If the sulfur recovery plant 
consists of multiple process trains or release points the owner or 
operator shall comply with the 2,500 ppmv limit for each process train 
or release point or comply with a flow rate weighted average of 2,500 
ppmv for all release points from the sulfur recovery plant; or
    (ii) For sulfur recovery plant with a reduction control system not 
followed by incineration, the owner or operator shall not discharge or 
cause the discharge of any gases into the atmosphere in excess of 3,000 
ppm by volume of reduced sulfur compounds and 100

[[Page 334]]

ppm by volume of hydrogen sulfide (H2S), each calculated as 
ppm SO2 by volume (dry basis) at zero percent excess air; or
    (iii) For systems using oxygen enrichment, the owner or operator 
shall calculate the applicable emission limit using Equation 2 of this 
section:
[GRAPHIC] [TIFF OMITTED] TR24JN08.001

Where:

ESS = Emission rate of SO2 for small sulfur 
recovery plant, ppmv.

    (3) Periods of maintenance of the sulfur pit, during which the 
emission limits in paragraphs (f)(1) and (2) shall not apply, shall not 
exceed 240 hours per year. The owner or operator must document the time 
periods during which the sulfur pit vents were not controlled and 
measures taken to minimize emissions during these periods. Examples of 
these measures include not adding fresh sulfur or shutting off vent 
fans.
    (g) Each owner or operator of an affected fuel gas combustion device 
shall comply with the emission limits in paragraphs (g)(1) through (3) 
of this section.
    (1) For each fuel gas combustion device, the owner or operator shall 
comply with either the emission limit in paragraph (g)(1)(i) of this 
section or the fuel gas concentration limit in paragraph (g)(1)(ii) of 
this section.
    (i) The owner or operator shall not discharge or cause the discharge 
of any gases into the atmosphere that contain SO2 in excess 
of 20 ppmv (dry basis, corrected to 0 percent excess air) determined 
hourly on a 3-hour rolling average basis and SO2 in excess of 
8 ppmv (dry basis, corrected to 0 percent excess air), determined daily 
on a 365 successive day rolling average basis; or
    (ii) The owner or operator shall not burn in any fuel gas combustion 
device any fuel gas that contains H2S in excess of 162 ppmv 
determined hourly on a 3-hour rolling average basis and H2S 
in excess of 60 ppmv determined daily on a 365 successive calendar day 
rolling average basis.
    (2) For each process heater with a rated capacity of greater than 40 
million British thermal units per hour (MMBtu/hr), the owner or operator 
shall not discharge to the atmosphere any emissions of NOX in 
excess of 40 ppmv (dry basis, corrected to 0 percent excess air) on a 
24-hour rolling average basis.
    (3) Except as provided in paragraphs (h) and (i) of this section, 
the owner or operator of an affected flare shall not allow flow to each 
affected flare during normal operations of more than 7,080 standard 
cubic meters per day (m\3\/day) (250,000 standard cubic feet per day 
(scfd)) on a 30-day rolling average. The owner or operator of a newly 
constructed or reconstructed flare shall comply with the emission limit 
in this paragraph by no later than the date that flare becomes an 
affected flare subject to this subpart. The owner or operator of a 
modified flare shall comply with the emission limit in this paragraph by 
no later than 1 year after that flare becomes an affected flare subject 
to this subpart.
    (h) The combustion in a flare of process upset gases or fuel gas 
that is released to the flare as a result of relief valve leakage or 
other emergency malfunctions is exempt from paragraph (g) of this 
section.
    (i) In periods of fuel gas imbalance that are described in the flare 
management plan required in section 60.103a(a), compliance with the 
emission limit in paragraph (g)(3) of this section is demonstrated by 
following the procedures and maintaining records described in the flare 
management plan to document the periods of excess fuel gas.