Current through Register Vol. 50, No. 9, March 1, 2024
RELATES TO: KRS Chapter 224
NECESSITY, FUNCTION, AND CONFORMITY:
KRS
224.10-100 requires the Environmental and
Public Protection Cabinet to prescribe administrative regulations for the
prevention, abatement, and control of air pollution. This administrative
regulation provides for the control of emissions from existing petroleum
refineries.
Section 1. Applicability.
The provisions of this administrative regulation shall apply to each affected
facility commenced before the classification date defined below.
Section 2. Definitions. As used in this
administrative regulation, all terms not defined herein shall have the meaning
given them in
401 KAR
50:010.
(1) "Affected
facility" means sulfur recovery units, fluid catalytic cracking unit
regenerators, fluid catalytic cracking unit incinerator-waste heat boilers and
fuel gas combustion devices at a petroleum refinery in any county classified VA
with respect to sulfur dioxide.
(2)
"Petroleum refinery" means any facility engaged in producing gasoline,
kerosene, distillate fuel oils, residual fuel oils, lubricants, or other
products through distillation of petroleum or reforming of unfinished petroleum
derivatives.
(3) "Petroleum" means
the crude oil removed from the earth and the oils derived from tar sands, shale
and coal.
(4) "Process gas" means
any gas generated by a petroleum refinery process unit, except fuel gas and
process upset gas as defined in this section.
(5) "Fuel gas" means any gas which is
generated by a petroleum refinery process unit and which is combusted,
including any gaseous mixture of natural gas and fuel gas which is
combusted.
(6) "Process upset gas"
means any gas generated by a petroleum refinery process unit as a result of
start-up, shutdown, upset or malfunction.
(7) "Refinery process unit" means any segment
of the petroleum refinery in which a specific processing operation is
conducted.
(8) "Fuel gas combustion
device" means any equipment, such as process heaters, boilers and flares used
to combust fuel gas, but does not include fluid coking unit and fluid catalytic
cracking unit incinerator-waste heat boilers, facilities combusting coke oven
gas in a by-product coke manufacturing plant, or facilities in which gases are
combusted to produce sulfur or sulfuric acid.
(9) "Classification date" means June 11, 1973
for any fluid catalytic cracking unit catalyst regenerator or fuel gas
combustion device; October 4, 1976 for any sulfur recovery unit; and June 6,
1979 for fluid catalytic cracking unit incinerator-waste heat
boilers.
Section 3.
Standard for Sulfur Dioxide.
(1) No owner or
operator subject to the provisions of this administrative regulation shall burn
in any fuel gas combustion device any fuel gas which contains hydrogen sulfide
in excess of 230 mg/dscm (one-tenth (0.10) gr/dscf), except as provided in
subsection (2) of this section. The combustion of process upset gas in a flare,
or the combustion in a flare of process gas or fuel gas which is released to
the flare as a result of relief valve leakage, is exempt from this
section.
(2) The owner or operator
may elect to treat the gases resulting from the combustion of fuel gas in a
manner which limits the release of sulfur dioxide to the atmosphere if it is
shown to the satisfaction of the cabinet that this prevents sulfur dioxide
emissions as effectively as compliance with the requirements of subsection (1)
of this section.
(3) No owner or
operator subject to the provisions of this administrative regulation shall
discharge or cause the discharge into the atmosphere from any Claus sulfur
recovery plant any gases containing in excess of:
(a) 0.025 percent by volume of sulfur dioxide
at zero percent oxygen on a dry basis if emissions are controlled by an
oxidation control system, or a reduction control system followed by
incineration; or
(b) 0.030 percent
by volume of reduced sulfur compounds and 0.0010 percent by volume of hydrogen
sulfide calculated as sulfur dioxide at zero percent oxygen on a dry basis if
emissions are controlled by a reduction control system not followed by
incineration.
Section
4. Monitoring and Reporting.
(1)
For any fluid catalytic cracking unit catalyst regenerator which utilizes an
incinerator-waste heat boiler to combust the exhaust gases from the catalyst
regenerator, the owner or operator shall record daily the conversion factors
used to convert monitored data (ppm) into units of the standard (lb/hr), the
data used to calculate the conversion factor and the hourly emission rate in
pounds per hour of sulfur dioxide.
(2) For the purpose of reports under
401 KAR 61:005
periods of excess emissions that shall be reported for sulfur dioxide are
defined as follows:
(a) Any three (3) hour
period during which the average concentration of hydrogen sulfide in any fuel
gas combusted in any fuel gas combustion device subject to Section 3(1) of this
administrative regulation exceeds 230 mg/dscm (one-tenth (0.10) gr/dscf), if
compliance is achieved by removing hydrogen sulfide from the fuel gas before it
is burned; or any three (3) hour period during which the average concentration
of sulfur dioxide in the gases discharged into the atmosphere from any fuel gas
combustion device subject to Section 3(2) of this administrative regulation
exceeds the level specified in Section 3(2) of this administrative regulation
if compliance is achieved by removing sulfur dioxide from the combusted fuel
gases.
(b) Any twelve (12) hour
period during which the average concentration of sulfur dioxide in the gases
discharged into the atmosphere from any Claus sulfur recovery plant subject to
Section 3(3) of this administrative regulation exceeds 250 ppm at zero percent
oxygen on a dry basis if compliance with Section 3(3) of this administrative
regulation is achieved through the use of an oxidation control system or a
reduction control system followed by incineration; or any twelve (12) hour
period during which the average concentration of hydrogen sulfide or reduced
sulfur compounds in the gases discharged into the atmosphere of any Claus
sulfur plant subject to Section 3(3) of this administrative regulation exceeds
ten (10) ppm or 300 ppm, respectively, at zero percent oxygen and on a dry
basis if compliance is achieved through the use of a reduction system not
followed by incineration.
(c) Any
six (6) hour period which the average emissions (arithmetic average of six (6)
contiguous one (1) hour periods) of sulfur dioxide as measured by a continuous
monitoring system for a fluid catalyst cracking unit exceed 640.0 pounds per
hour.
Section
5. Test Methods and Procedures (filed by reference in
401 KAR
50:015) .
(1) For the
purpose of determining compliance with Section 3(1) and (2) of this
administrative regulation, Reference Method 11 shall be used to determine the
concentration of hydrogen sulfide and Reference Method 6 shall be used to
determine the concentration of sulfur dioxide.
(a) If Reference Method 11 is used, the gases
sampled shall be introduced into the sampling train at approximately
atmospheric pressure. Where refinery fuel gas lines are operating at pressures
substantially above atmosphere, this may be accomplished with a flow control
valve. If the line pressure is high enough to operate the sampling train
without a vacuum pump, the pump may be eliminated from the sampling train. The
sample shall be drawn from a point near the centroid of the fuel gas line. The
minimum sampling time shall be ten (10) minutes and the minimum sampling volume
0.01 dscm (0.35 dscf) for each sample. The arithmetic average of two (2)
samples of equal sampling time shall constitute one (1) run. Samples shall be
taken at approximately one (1) hour intervals. For most fuel gases, sample
times exceeding twenty (20) minutes may result in depletion of the collecting
solution, although fuel gases containing low concentrations of hydrogen sulfide
may necessitate sampling for longer periods of time.
(b) If Reference Method 6 is used, Reference
Method 1 shall be used for velocity traverses and Reference Method 2 for
determining velocity and volumetric flow rate. The sampling site for
determining sulfur dioxide concentration by Reference Method shall be the same
as for determining volumetric flow rate by Reference Method 2. The sampling
point in the duct for determining sulfur dioxide concentration by Reference
Method 6 shall be at the centroid of the cross section if the cross-sectional
area is less than five (5) square meters (fifty-four (54) square feet) or at a
point no closer to the walls than one (1) meter (thirty-nine (39) inches) if
the cross-sectional area is five (5) square meters or more and the centroid is
more than one (1) meter from the wall. The sample shall be extracted at a rate
proportional to the gas velocity at the sampling point. The minimum sampling
time shall be ten (10) minutes and the minimum sampling volume 0.01 dscm (0.35
dscf) for each sample. The arithmetic average of two (2) samples of equal
sampling time shall constitute one (1) run. Samples shall be taken at
approximately one (1) hour intervals.
(2) For the purpose of determining compliance
with Section 3(3) of this administrative regulation, Reference Method 6 shall
be used to determine the concentration of sulfur dioxide and Reference Method
15 shall be used to determine the concentration of sulfur dioxide and reduced
sulfur compounds.
(a) If Reference Method 6 is
used, the procedure outlined in subsection (1)(b) of this section shall be
followed except that each run shall span a minimum of four (4) consecutive
hours of continuous sampling. A number of separate samples may be taken for
each run, provided the total sampling time of these samples adds up to a
minimum of four (4) consecutive hours. Where more than one (1) sample is used,
the average sulfur dioxide concentration for the run shall be calculated as the
time weighted average of the sulfur dioxide concentration for each sample
according to the formula in Appendix A of this administrative
regulation.
(b) If Reference Method
15 is used, each run shall consist of sixteen (16) samples taken over a minimum
of three (3) hours. The sampling point shall be at the centroid of the cross
section of the duct if the cross-sectional area is less than five (5) square
meters (fifty-four (54) square feet) or at a point no closer to the walls than
one (1) meter (thirty-nine (39) inches) if the cross-sectional area is five (5)
square meters or more and the centroid is more than one (1) meter from the
wall. To insure minimum residence time for the sample inside the sample lines,
the sampling rate shall be at least three (3) liters/minute (one-tenth (0.1)
cfm). The sulfur dioxide equivalent for each run shall be calculated as the
arithmetic average of the sulfur dioxide equivalent of each sample during the
run. Reference Method 4 shall be used to determine the moisture content of the
gases. The sampling point for Reference Method 4 shall be adjacent to the
sampling point for Reference Method 15. The sample shall be extracted at a rate
proportional to the gas velocity at the sampling point. Each run shall span a
minimum of four (4) consecutive hours of continuous sampling. A number of
separate samples may be taken for each run provided the total sampling time of
these samples adds up to a minimum of four (4) consecutive hours. Where more
than one (1) sample is used, the average moisture content for the run shall be
calculated as the time weighted average of the moisture content of each sample
according to the formula in Appendix A of this administrative
regulation.
Section
6. Compliance Timetable.
(1) The
owner or operator of a sulfur recovery plant shall be required to complete the
following:
(a) Submit a final control plan for
achieving compliance with Section 3(3) of this administrative regulation no
later than September 1, 1979.
(b)
Award the control system contract no later than December 1, 1979.
(c) Initiate on-site construction or
installation of emission control equipment by October 1, 1980.
(d) On-site construction or installation of
emission control equipment shall be completed no later than May 1,
1981.
(e) Final compliance shall be
achieved no later than July 1, 1981.
(2) The owner or operator of a fuel gas
combustion device shall be required to complete the following:
(a) Submit a final control plan for achieving
compliance with Section 3(1) of this administrative regulation no later than
August 1, 1980.
(b) Purchase
control equipment no later than September 1, 1980.
(c) Initiate on-site construction or
installation of emission control equipment by October 1, 1980.
(d) On-site construction or installation of
emission control equipment shall be completed no later than August 1,
1981.
(e) Final compliance shall be
achieved no later than October 1, 1981.
(3) The owner or operator shall be required
to demonstrate compliance with all other provisions of this administrative
regulation no later than June 6, 1979.
Section 7. Appendix A - Time Weighted Average
of SO2 Concentration.
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Where:
CR = SO2
concentration for the run.
N = Number of samples.
Csi = SO2
concentration for sample 1.
tsi = Continuous sampling time of sample
i.
T = Total continuous sampling time of all N samples.
Section 8. Appendix B - Equation
for the Time Weighted Average of the Moisture Content.
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STATUTORY AUTHORITY:
KRS
224.10-100