SDAPCD RULE X-DB STDS.OF PERF.FOR INDUS.-COMM.-INST.STM.GEN
LAST REVISED 09/21/93

          
          SUBPART Db -   STANDARDS OF PERFORMANCE FOR INDUSTRIAL-
                         COMMERCIAL-INSTITUTIONAL STEAM GENERATING UNITS
                         (Adopted 12-15-87; Delegation Effective 7-18-89;
                          Rev. Effective 9-21-93)


               RULE 260.40b.  APPLICABILITY AND DEFINITION OF
                              AFFECTED FACILITY (Rev. Effective 3-14-89)

               (a)  The affected facility to which this subpart applies is
          each steam generating unit that commences construction,
          modification, or reconstruction after June 19, 1984, and that has
          a heat input capacity from fuels combusted in the steam
          generating unit of more than 29 MW (100 million BTU/hour).

               (b)  Any affected facility meeting the applicability
          requirements under Section (a) of this rule and commencing
          construction, modification, or reconstruction after June 19,
          1984, but on or before June 19, 1986, is subject to the following
          standards:

                    (1)  Coal-fired affected facilities having a heat input
               capacity between 29 and 73 MW (100 and 250 million
               BTU/hour), inclusive, are subject to the particulate matter
               and nitrogen oxides standards under this subpart.

                    (2)  Coal-fired affected facilities having a heat input
               capacity greater than 73 MW (250 million BTU/hour) and
               meeting the applicability requirements under Subpart D
               (Standards of Performance for Fossil-Fuel Fired Steam
               Generators; Rule 260.40) are subject to the particulate
               matter and nitrogen oxides standards under this subpart and
               to the sulfur dioxide standards under Subpart D (Rule
               260.43).

                    (3)  Oil-fired affected facilities having a heat input
               capacity between 29 and 73 MW (100 and 250 million
               BTU/hour), inclusive, are subject to the nitrogen oxides
               standards under this subpart.

                    (4)  Oil-fired affected facilities having a heat input
               capacity greater than 73 MW (250 million BTU/hour) and
               meeting the applicability requirements under Subpart D
               (Standards of Performance for Fossil-Fuel-Fired Steam
               Generators: Rule 260.40) are also subject to the nitrogen
               oxides standards under this subpart and the particulate
               matter and sulfur dioxide standards under Subpart D (Rules
               260.42 and 260.43).

               (c)  Affected facilities which also meet the applicability
          requirements under Subpart  J (Standards of Performance for
          Petroleum Refineries; Rule 260.104) are subject to the
          particulate matter and nitrogen oxides standards under this
          subpart and the sulfur dioxide standards under Subpart J (Rule
          260.104).

               (d)  Affected facilities which also meet the applicability
          requirements under Subpart  E (Standards of Performance for
          Incinerators; Rule 260.50) are subject to the nitrogen oxides and
          particulate matter standards under this subpart.
               
               (e)  Steam generating units meeting the applicability
          requirements under Subpart Da (Standards of Performance for
          Electric Utility Steam Generating Units; Rule 260.40a) are not
          subject to this subpart.

               (f)  Any change to an existing stream generating unit for
          the sole purpose of combusting gases containing TRS (Total
          Reduced Sulfur) as defined under Section 60.281, Title 40, Code
          of Federal Regulations, is not considered a modification under
          Rule 260.14 and the steam generating unit is not subject to this
          subpart.


               RULE 260.41b.  DEFINITIONS   (Rev. Effective 9-21-93)

               As used in this subpart, all terms not defined herein shall
          have the meaning given them in the Act and in Subpart A of this
          Regulation.

               (a)  "Annual Capacity Factor" means the ratio between the
          actual heat input to a steam generating unit from the fuels
          listed in Rules 260.42b(a), 260.43b(a), or 260.44b(a), as
          applicable, during a calendar year and the potential heat input
          to the steam generating unit had it been operated for 8,760 hours
          during a calendar year at the maximum steady state design heat
          input capacity.  In the case of steam generating units that are
          rented or leased, the actual heat input shall be determined based
          on the combined heat input from all operations of the affected
          facility in a calendar year.

               (b)  "Byproduct/Waste" means any liquid or gaseous substance
          produced at chemical manufacturing plants or petroleum refineries
          (except natural gas, distillate oil, or residual oil) and
          combusted in a steam generating unit for heat recovery or for
          disposal.  Gaseous substances with carbon dioxide levels greater
          than 50 percent or carbon monoxide levels greater than 10 percent
          are not byproduct/waste for the purposes of this subpart.

               (c)  "Chemical Manufacturing Plants" means industrial plants
          which are classified by the Department of Commerce under Standard
          Industrial Classification (SIC) Code 28.

               (d)  "Coal" means all solid fuels classified as anthracite,
          bituminous, subbituminous, or lignite by the American Society of
          Testing and Materials in ASTM D388-77, Standard Specification for
          Classification of Coals by Rank (incorporated by reference (IBR)
          - 40 CFR, see Section 60.17) coal refuse and petroleum coke.
          Coal-derived synthetic fuels, including but not limited  to
          solvent refined coal, gasified coal, coal-oil mixtures and coal-
          water mixtures, are also included in this definition for the
          purpose of this subpart.

               (e)  "Coal Refuse" means any byproduct of coal mining or
          coal cleaning operations with an ash content greater than 50
          percent, by weight, and a heating value less than 13,900 kJ/kg
          (6,000 BTU/lb) on a dry basis.

               (f)  "Combined Cycle System" means a system in which a
          separate source, such as a gas turbine, internal combustion
          engine, kiln, etc., provides exhaust gas to a heat recovery steam
          generating unit.

               (g)  "Conventional Technology" means wet flue gas
          desulfurization (FGD) technology, dry FGD technology, atmospheric
          fluidized bed combustion technology, and oil hydrodesulfurization
          technology.

               (h)  "Distillate Oil" means fuel oils which contain 0.05
          weight percent nitrogen or less and comply with the
          specifications for fuel oils number 1 and 2, as defined by the
          American Society of Testing and Materials in ASTM D396-78,
          Standard Specifications for Fuel Oil (IBR - see 40 CFR, Section
          60.17).

               (i)  "Dry Flue Gas Desulfurization Technology" means a
          sulfur dioxide control system that is located downstream of the
          steam generating unit and removes sulfur oxides from the
          combustion gases of the steam generating unit by contacting the
          combustion gases with an alkaline slurry or solution and forming
          a dry powder material.  This definition includes devices where
          the dry powder material is subsequently converted to another
          form.  Alkaline slurries or solutions used in dry flue gas
          desulfurization technology include but are not limited to lime
          and sodium.

               (j)  "Duct Burner" means a device that combusts fuel and
          which is placed in the exhaust duct from another source, such as
          a stationary gas turbine, internal combustion engine, kiln, etc.,
          to allow the firing of additional fuel to heat the exhaust gases
          before the exhaust gases enter a heat recovery steam generating
          unit.

               (k)  "Emerging Technology" means any sulfur dioxide control
          system that is not defined as a conventional technology under
          this rule, and for which the owner or operator of the facility
          has applied to the Administrator and received approval to operate
          as an emerging technology under Rule 260.49b(a)(4).

               (l)  "Federally Enforceable" means all limitations and
          conditions which are enforceable by the Administrator or the
          Control Officer including those requirements developed pursuant
          to 40 CFR Parts 60 and 61, requirements within any applicable
          State Implementation Plan, and any permit requirements
          established pursuant to 40 CFR 51.18 and 40 CFR 51.24.

               (m)  "Fluidized Bed Combustion Technology" means combustion
          of fuel in a bed or series of beds (including but not limited to
          bubbling bed units and circulating bed units) of limestone
          aggregate (or other sorbent materials) in which these materials
          are forced upward by the flow of combustions air and the gaseous
          products of combustion.

               (n)  "Fuel Pretreatment" means a process that removes a
          portion of the sulfur in a fuel before combustion of the fuel in
          a steam generating unit.

               (o)  "Full Capacity" means operation of the steam generating
          unit at 90 percent or more of the maximum steady state design
          heat input capacity.

               (p)  "Heat Input" means heat derived from combustion of fuel
          in a steam generating unit and does not include the heat input
          from preheated combustion air, recirculated flue gases, or
          exhaust gases from other sources, such as gas turbines, internal
          combustion engines, kilns, etc.

               (q)  "Heat Release Rate" means the steam generating unit
          design heat input capacity (in MW or BTU/hour) divided by the
          furnace volume (in cubic meters or cubic feet); the furnace
          volume is that volume bounded by the front furnace wall where the
          burner is located, the furnace side waterwall, and extending to
          the level just below or in from of the first row of convection
          pass tubes.

               (r)  "Heat Transfer Medium" means any material which is used
          to transfer heat from one point to another point.

               (s)  "High Heat Release Rate" means a heat release rate
          greater than 730,000 J/sec-m3 (70,000 BTU/hour-ft3).

               (t)  "Lignite" means a type of coal classified as lignite A
          or lignite B by the American Society of Testing and Materials in
          ASTM D388-77, Standard Specification for Classification of Coals
          by Rank (IBR see 40 CFR, Section 60.17).

               (u)  "Low Heat Release Rate" means a heat release rate of
          730,000 J/sec-m3 (70,000 BTU/hour-ft3) or less.

               (v)  "Mass-Feed Stoker Steam Generating Unit" means a steam
          generating unit where solid fuel is introduced directly into a
          retort or is fed directly onto a grate where it is combusted.

               (w)  "Maximum Heat Input Capacity" means the ability of a
          steam generating unit to combust a stated maximum amount of fuel
          on a steady state basis, as determined by the physical design and
          characteristics of the steam generating unit.

               (x)  "Municipal-Type Solid Waste" means refuse, more than 50
          percent of which is waste consisting of a mixture of paper, wood,
          yard wastes, food wastes, plastics, leather, rubber, and  other
          combustible materials, and noncombustible materials such as glass
          and rock.

               (y)  "Natural Gas" means (1) a naturally occurring mixture
          of hydrocarbon and nonhydrocarbon gases found in geologic
          formations beneath the earth's surface, of which the principal
          constituent is methane or (2) liquid petroleum gas, as defined by
          the American Society for Testing and Materials in ASTM D1835-82,
          "Standard Specification for Liquid Petroleum Gases" (IBR - see 40
          CFR, Section 60.17).

               (z)  "Noncontinental Area" means the State of Hawaii, the
          Virgin-Islands, Guam, American Samoa, the Commonwealth of Puerto
          Rico, or the Northern Mariana Islands.

               (aa) "Oil" means crude oil or petroleum or a liquid fuel
          derived from crude oil or petroleum, including distillate and
          residual oil.

               (bb) "Petroleum Refinery" means industrial plants which are
          classified by the Department of Commerce under Standard
          Industrial Classification (SIC), Code 29.

               (cc) "Potential Sulfur Dioxide Emission Rate" means the
          theoretical sulfur dioxide emissions (nanograms per joule,
          lbs/million BTU heat input) that would result from combusting
          fuel in an uncleaned state and without using emission control
          systems.

               (dd) "Process Heater" means a device which is primarily used
          to heat a material to initiate or promote a chemical reaction in
          which the material participates as a reactant or catalyst.

               (ee) "Pulverized Coal-Fired Steam Generating Unit" means a
          steam generating unit in which pulverized coal is introduced into
          an air stream that carries the coal to the combustion chamber of
          the steam generating unit where it is fired in suspension.  This
          includes both conventional pulverized coal-fired and
          micropulverized coal-fired steam generating units.

               (ff) "Residual Oil" means crude oil, fuel oils numbers 1 and
          2 which have a nitrogen content of greater than 0.05 weight
          percent, and all fuel oils number 4, 5 and 6, as defined by the
          American Society of Testing and Materials in ASTM D396-78,
          Standard Specifications for Fuel Oils (IBR - 40 CFR, Section
          60.17).

               (gg) "Spreader Stoker Steam Generating Unit" means a steam
          generating unit in which solid fuel is introduced to the
          combustion zone by a mechanism that throws the fuel onto a grate
          from above.  Combustion takes place both in suspension and on the
          grate.

               (hh) "Steam Generating Unit" means a device which combusts
          any fuel or byproduct/ waste to produce steam or to heat water or
          any other heat transfer medium.  This term includes any
          municipal-type solid waste incinerator with a heat recovery steam
          generating unit or any steam generating unit which combusts fuel
          and is part of a cogeneration system or a combined cycle system.
          This term does not include process heaters as they are defined in
          this subpart.

               (ii) "Steam Generating Unit Operating Day" means a 24-hour
          period between 12:00 midnight and the following midnight during
          which any fuel is combusted at any time in the steam generating
          unit.  It is not necessary for fuel to be combusted continuously
          for the entire 24-hour period.

               (jj) "Low Sulfur Oil" means an oil that contains no more
          than 0.5 weight percent sulfur or that, when combusted without
          sulfur dioxide emission control, has a sulfur dioxide emission
          rate equal to or less than 215 nanograms per joule (0.5
          lb/million BTU) heat input.  (Rev. Effective 9-21-93)

               (kk) "Wet Flue Gas Desulfurization Technology" means a
          sulfur dioxide control system that is located downstream of the
          steam generating unit and removes sulfur oxides from the
          combustion gases of the steam generating by contacting the
          combustion gas with an alkaline slurry or solution and forming a
          liquid material.  This definition applies to devices where the
          aqueous liquid material product of this contact is subsequently
          converted to other forms.  Alkaline reagents used in wet flue gas
          desulfurization technology include, but are not limited to, lime,
          limestone and sodium.

               (ll) "Wet Scrubber System" means any emission control device
          which mixes an aqueous stream or slurry with the exhaust gases
          from a steam generating unit to control emissions of particulate
          matter or sulfur dioxide.

               (mm) "Wood" means wood, wood residue, bark, or any
          derivative fuel or residue thereof, in any form, including, but
          not limited to, sawdust, sanderdust, wood chips, scraps, slabs,
          millings, shavings, and processed pellets made from wood or other
          forest residues.


               RULE 260.42b.  STANDARD FOR SULFUR DIOXIDE
                              (Effective 3-14-89; Rev. Effective 9/21/93)

               (a)  Except as provided in Sections (b), (c), or (d) of this
          rule on and after the date on which the performance test is
          completed or required to be completed under Rule 260.8 of this
          Regulation, whichever date comes first, no owner or operator of
          an affected facility that combusts coal or oil shall cause to be
          discharged into the atmosphere any gases that contain sulfur
          dioxide in excess of 10 percent (0.10) of the potential sulfur
          dioxide emission rate (90 percent reduction)  and that contain
          sulfur dioxide in excess of the emission limit determined
          according to the following formula:

                         Es = (KaHa  +  KbHb)/(Ha  +  Hb)

          where:


               Es   is the sulfur dioxide emission limit, in nanograms per
                    joule (ng/J) or lbs/million BTU heat input,

               Ka   is 520 ng/J (or 1.2 lbs/million BTU),

               Kb   is 340 ng/J (or 0.80 lbs/million BTU),

               Ha   is the heat input from the combustion of coal, in J
                    (million BTU),

               Hb   is the heat input from the combustion of oil, in J
                    (million BTU).

               Only the heat input supplied to the affected facility from
          the combustion of coal and oil is counted under this rule.  No
          credit is provided for the heat input to the affected facility
          from the combustion of natural gas, wood, municipal-type solid
          waste, or other fuels or heat input to the affected facility from
          exhaust gases from another source, such as gas turbines, internal
          combustion engines, kilns, etc.

               (b)  On and after the date on which the performance test is
          completed or is required to be completed under Rule 260.8 of this
          Regulation, whichever comes first, no owner or operator of an
          affected facility that combusts coal refuse alone in a fluidized
          bed combustion steam generating unit shall cause to be discharged
          into the atmosphere any gases that contain sulfur dioxide in
          excess of 20 percent of the potential sulfur dioxide emission
          rate (80 percent reduction) and that contain sulfur dioxide in
          excess of 520 ng/J (lbs/million BTU) heat input.  If coal or oil
          is fired with coal refuse, the affected facility is subject to
          Sections (a) or (d) of this rule, as applicable.

               (c)  On and after the date on which the performance test is
          completed or is required to be completed under Rule 260.8 of this
          Regulation, whichever comes first, no owner or operator of an
          affected facility that combusts coal or oil, either alone or in
          combination with any other fuel, and that uses an emerging
          technology for the control of sulfur dioxide emissions, shall
          cause to be discharged into the atmosphere any gases that contain
          sulfur dioxide in excess of 50 percent of the potential sulfur
          dioxide emission rate (50 percent reduction) and that contain
          sulfur dioxide in excess of the emission limit determined accord-
          ing to the following formula:

                         Es = (KcHc  +  KdHd)/(Hc  +  Hd)

          where:

               Es   is the sulfur dioxide emission limit, expressed in ng/J
                    (lbs/million BTU) heat input,

               Kc   is 260 ng/J (0.60 lbs/million BTU),

               Kd   is 170 ng/J (0.40 lbs/million BTU),

               Hc   is the heat input from the combustion of coal, J
                    (million BTU), and

               Hd   is the heat input from the combustion of oil, J
                    (million BTU).

               Only the heat input supplied to the affected facility from
          the combustion of coal and oil is counted under this rule.  No
          credit is provided for the heat input to the affected facility
          from the combustion of natural gas, wood, municipal-type solid
          waste, or other fuels, or from the heat input to the affected
          facility from exhaust gases from another source, such as gas
          turbines, internal combustion engines, kilns, etc.

               (d)  On and after the date on which the performance test is
          completed or required to be completed under Rule 260.8 of this
          Regulation, whichever comes first, no owner or operator of an
          affected facility listed in Subsections (d)(1), (d)(2), or
          (d)(3), of this rule shall cause to be discharged into the
          atmosphere any gases that contain sulfur dioxide in excess of 520
          ng/J (1.2 lbs/million BTU) heat input if the affected facility
          combusts coal, or 215 ng/J (0.50 lbs/ million BTU) heat input if
          the affected facility combusts oil other than low sulfur oil.
          The following affected facilities under this section are not
          subject to percent reduction requirements:   (Rev. Effective 9-
          21-93)

                    (1)  Affected facilities that have any annual capacity
               factor for coal and oil of 30 percent (0.30) or less and are
               subject to a federally enforceable permit limiting the
               operation of the affected facility to an annual capacity
               factor for coal and oil to 30 percent (0.30) or less;

                    (2)  Affected facilities located in a noncontinental
               area; and

                    (3)  Affected facilities combusting coal or oil, alone
               or in combination with any other fuel, in a duct burner as
               part of a combined cycle system where 30 percent (0.30) or
               less of the heat input to the steam generating unit is from
               combustion of coal and oil in the duct burner and 70 percent
               (0.70) or more of the heat input to the steam generating
               unit is from the exhaust gases entering the duct burner.

               (e)  Except as provided in Section (f) of this rule,
          compliance with the emission limits, fuel oil sulfur limits,
          and/or percent reduction requirements under this rule are
          determined on a rolling 60-minute average basis.  (Rev. Effective
          9-21-93)

               (f)  Except as provided in Subsection (j)(2) of this rule,
          compliance with the emission limits or fuel oil sulfur limits
          under this rule is determined on a 24-hour average basis for
          affected facilities that have a federally enforceable permit
          limiting the annual capacity factor for oil to 10 percent or
          less, combust only low sulfur oil, and do not combust any other
          fuel.  (Effective 9-21-93)

               (g)  Except as provided in Section (i) of this rule, the
          sulfur dioxide emission limits and percent reduction requirements
          under this section apply at all times, including periods of
          startup, shutdown, and malfunction.

               (h)  Reductions in the potential sulfur dioxide emission
          rate through fuel pretreatment are not credited toward the
          percent reduction requirement under Section (c) of this rule
          unless:

                    (1)  Fuel pretreatment results in a 50 percent or
               greater reduction in potential sulfur dioxide emissions and

                    (2)  Emissions from the pretreated fuel (without
               combustion or post combustion sulfur dioxide control) are
               equal to or less than the emission limits specified in
               Section (c) of this rule.

               (i)  An affected facility subject to Sections (a), (b), or
          (c) of this rule may combust low sulfur oil or natural gas when
          the sulfur dioxide control system is not being operated because
          of malfunction or maintenance of the sulfur dioxide control
          system.

               (j)  Affected facilities combusting only low sulfur oil are
          not subject to the percent reduction requirements in any section
          of this rule.  The owner or operator of an affected facility
          combusting low sulfur oil shall demonstrate that the oil meets
          the definition of low sulfur oil by:  (Effective 9-21-93)

                    (1)  following the performance testing procedures as
               described in Rules 260.45b(c) or 260.45b(d), and following
               the monitoring procedures as described in Rules 260.47b(a)
               or 260.47b(b) to determine sulfur dioxide emission rate or
               fuel oil sulfur content; or

                    (2)  maintaining fuel receipts as described in Rule
               260.49b(r).


               RULE 260.43b.  STANDARD FOR PARTICULATE MATTER
                                        (Rev. Effective 9-21-93)

               (a)  On and after the date on which the initial performance
          test is completed or is required to be completed under Rule 260.8
          of Subpart A of this Regulation, whichever comes first, no owner
          or operator of an affected facility which combusts coal or
          combusts mixtures of coal with other fuels, shall cause to be
          discharged into the atmosphere from the affected facility any
          gases which contain particulate matter in excess of the following
          emission limits:

                    (1)  22 ng/J (0.05 lbs/million BTU) heat input;

                         (i)  If the affected facility combusts only coal, or

                         (ii) If the affected facility combusts coal and
                    other fuels and has an annual capacity factor for the
                    other fuels of 10 percent (0.10) or less.

                    (2)  43 ng/J (0.10 lbs/million BTU) heat input if the
               affected facility combusts coal and other fuels and has an
               annual capacity factor for the other fuels greater than 10
               percent (0.10) and is subject to a federally enforceable
               requirement limiting operation of the affected facility to
               an annual capacity factor greater than 10 percent (0.10) for
               fuels other than coal.

                    (3)  86 ng/J (0.20 lbs/million BTU) heat input if the
               affected facility combusts coal or coal and other fuels, and

                         (i)  Has an annual capacity factor for coal or
                    coal and other fuels of 30 percent (0.30) or less,

                         (ii) Has a maximum heat input capacity of 73 MW
                    (250 million BTU/hour) or less,

                         (iii)Has a federally enforceable requirement
                    limiting operation of the affected facility to an
                    annual capacity factor of 30 percent (0.30) or less for
                    coal or coal and other solid fuels, and

                         (iv) Construction of the affected facility
                    commenced after June 19, 1984 and before November 25,
                    1986.

               (b)  On and after the date on which the performance test is
          completed or required to be completed under Rule 260.8 of this
          Regulation, whichever date comes first, no owner or operator of
          an affected facility that combusts oil (or mixtures of oil with
          other fuels) and uses a conventional or emerging technology to
          reduce sulfur dioxide emissions shall cause to be discharged into
          the atmosphere from that affected facility any gases that contain
          particulate matter in excess of 43 ng/J (0.10 lbs/million BTU)
          heat input.  (Rev. Effective 9-21-93)

               (c)  On or after the date which the initial performance test
          is completed or is required to be completed under Rule 260.8 of
          this Regulation, whichever date comes first, no owner or operator
          of an affected facility which combust wood, or wood with other
          fuels, except coal, shall cause to be discharged from  that
          affected facility any gases which contain particulate matter in
          excess of the following emission limits:

                    (1)  43 ng/J (0.10 lbs/million BTU) heat input if the
               affected facility has an annual capacity factor greater than
               30 percent (0.30) for wood.

                    (2)  86 ng/J (0.20 lbs/million BTU) heat input if:

                         (i)  The affected facility has an annual capacity
                    factor of 30 percent (0.30) or less for wood,

                         (ii) Is subject to a federally enforceable
                    requirement limiting operation of the affected facility
                    to an annual capacity factor of 30 percent (0.30) or
                    less for wood, and

                         (iii)Has a maximum heat input capacity of 73 MW
                    (250 million BTU/hour) or less.

               (d)  On or after the date on which the initial performance
          test is completed or is required to be completed under Rule 260.8
          of this Regulation, whichever date comes first, no owner or
          operator of an affected facility which combusts municipal-type
          solid wastes or mixtures of municipal-type solid waste with other
          fuels, shall cause to be discharged into to the atmosphere from
          that affected facility any gases which contain particulate matter
          in excess of the following emission limits:

                    (1)  43 ng/J (0.10 lbs/million BTU) heat input;

                         (i)  If the affected facility combusts only
                    municipal-type solid waste, or

                         (ii) If the affected facility combusts municipal-
                    type solid waste and other fuels and has an annual
                    capacity factor for the other fuels of 10 percent
                    (0.10) or less.

                    (2)  86 ng/J (0.20 lbs/million BTU) heat input if the
               affected facility combusts municipal-type solid waste or
               municipal-type solid waste and other fuels, and

                         (i)  Has an annual capacity factor for municipal-
                    type solid waste and other fuels of 30 percent (0.30)
                    or less,

                         (ii) Has a maximum heat input capacity of 73 MW
                    (250 million BTU/hour) or less,

                         (iii)Has a federally enforceable requirement
                    limiting operation of the affected facility to an
                    annual capacity factor of 30 percent (0.30) for
                    municipal-type solid waste, or municipal-type solid
                    waste and other fuels, and

                         (iv) Construction of the affected facility
                    commenced after June 19, 1984 but before November 25,
                    1986.

               (e)  For the purposes of this rule the annual capacity
          factor is determined by dividing the actual input to the steam
          generating unit during the calendar year from the combustion of
          coal, wood, or municipal-type solid waste, and other fuels, as
          applicable, by the potential heat input to the steam generating
          unit if the steam generating unit had been operated for 8,760
          hours at the maximum design heat input capacity.

               (f)  On and after the date on which the initial performance
          test is completed or is required to be completed under Rule 260.8
          of this Regulation, whichever date comes first, no owner or
          operator of an affected facility that combusts coal, oil, wood,
          or mixtures of these fuels with any other fuels shall cause to be
          discharged into the atmosphere any gases which exhibit greater
          than 20 percent opacity (6-minute average), except for one 6-
          minute period per hour of not more than 27 percent opacity.
          (Rev. Effective 9-21-93)

               (g)  The particulate matter and opacity standards apply at
          all times, except during periods of startup, shutdown or
          malfunction.


               RULE 260.44b.  STANDARD FOR NITROGEN OXIDES
                              (Rev. Effective 9-21-93)

               (a)  Except as provided under Section (k) of this rule, on
          and after the date on which the initial performance test is
          completed or is required to be completed under Rule 260.8 of this
          Regulation, whichever date comes first, no owner or operator of
          an affected facility subject to the provisions of this rule which
          combusts only coal, oil, or natural gas shall cause to be
          discharged into the atmosphere from that affected facility any
          gases which contain nitrogen oxides (expressed as NO2) in excess
          of the following emission limits:  (Rev. Effective 9-21-93)

            (Figures in parenthesis represent lbs/million BTU heat input)

             FUEL/STEAM GENERATING UNIT TYPE               NITROGEN OXIDES(1)

          (1)  Natural gas and distillate oil, except (4):

               (i)  Low heat release rate                           43 (.10)
               (ii) High heat release rate                          86 (.20)

          (2)  Residual oil:

               (i)  Low heat release rate                          130 (.30)
               (ii) High heat release rate                         170 (.40)

          (3)  Coal:

               (i)  Mass-feed stoker                               210 (.50)
               (ii) Spreader stoker and fluidized bed combustion   260 (.60)
               (iii)Pulverized coal                                300 (.70)
               (iv) Lignite, except (v)                            260 (.60)
               (v)  Lignite mined in North Dakota, South Dakota,
                    or Montana and combusted in a slag tap furnace 340 (.80)
               (vi) Coal-derived synthetic fuels                   210 (.50)

          (4)  Duct burner used in a combined cycle system:

               (i)  Natural gas and distillate oil                  86 (.20)
               (ii) Residual Oil                                   170 (.40)
          ___________________________________________________________________

          (1)  Emission limits ng/J (lbs/BTU) (expressed as NO2) heat input.

               (b)  Except as provided under Section (k) of this rule, on
          which the initial performance test is completed or is required to
          be completed under Rule 260.8 of this Regulation, whichever date
          comes first, no owner or operator of an affected facility which
          simultaneously combusts mixtures of coal, oil, or natural gas
          shall cause to be discharged into the atmosphere from that
          affected facility any gases which contain nitrogen oxides in
          excess of a limit determined by use of the following formula:

          En = [(ELgo x Hgo) + (ELro x Hro) + (ELc x Hc)]/(Hgo + Hro + Hc)

          where:

               En   is the nitrogen oxides emission limit, (calculated as
                    NO2), ng/J (lbs/million BTU),

               ELgo is the appropriate emission limit from Subsection
                    (a)(1) for combustion of natural gas or distillate oil,
                    ng/J (lbs/million BTU),

               Hgo  is the heat input from combustion of natural gas or
                    distillate oil,

               ELro is the appropriate emission limit from Subsection
                    (a)(2) for combustion of residual oil,

               Hro  is the heat input from combustion of residual oil,

               ELc  is the appropriate emission limit from Subsection
                    (a)(3) for combustion of coal, and

               Hc   is the heat input from combustion of coal.

               (c)  On and after the date on which the initial performance
          test is completed or is required to be completed under Rule 260.8
          of this Regulation, whichever comes first, no owner or operator
          of an affected facility which simultaneously combusts coal or
          oil, or a mixture of these fuels with natural gas, and wood,
          municipal-type solid waste, or any other fuel shall cause to be
          discharged into the atmosphere any gases which contain nitrogen
          oxides in excess of the emission limit for the coal or oil, or a
          mixture of these fuels with natural gas combusted in the affected
          facility, as determined pursuant to Sections (a) or (b) of this
          rule, unless the affected facility has an annual capacity factor
          for coal or oil, or mixture of these fuels with natural gas of 10
          percent (0.10) or less and is subject to a federally enforceable
          requirement which limits operation of the facility to an annual
          capacity factor of 10 percent (0.10) or less for coal, oil, or a
          mixture of these fuels with natural gas.

               (d)  On and after the date on which the initial performance
          test is completed or is required to be completed under Rule 260.8
          of this Regulation, whichever date comes first, no owner or
          operator of an affected facility which simultaneously combusts
          natural gas with wood, municipal-type solid waste, or  other
          solid fuel, except coal, shall cause to be discharged into the
          atmosphere from that affected facility any gases which contain
          nitrogen oxides in excess of 130 ng/J (0.30 lbs/million BTU) heat
          input unless the affected facility has an annual capacity factor
          for natural gas of 10 percent (0.10) or less and is subject to a
          federally enforceable requirement which limits operation of the
          affected facility to an annual capacity factor of 10 percent
          (0.10) or less for natural gas.

               (e)  On and after the date on which the initial performance
          test is completed or is required to be completed under Rule 260.8
          of this Regulation, whichever date comes first, no owner or
          operator of an affected facility which simultaneously combusts
          coal, oil, or natural gas with byproduct/wastes shall cause to be
          discharged into the atmosphere from that affected facility any
          gases which contain nitrogen oxides in excess of an emission
          limit determined by the following formula unless the affected
          facility has an annual capacity factor for coal, oil, and natural
          gas of 10 percent (0.10) or less and is subject to a federally
          enforceable requirement which limits operation of the affected
          facility to an annual capacity factor of 10 percent (0.10) or
          less.

          En = [(ELgo x Hgo) + (ELro x Hro) + (ELc x Hc)]/(Hgo + Hro + Hc)

          where:

               En   is the nitrogen oxides emission limit (expressed as
                    NO2), ng/J lbs/million BTU,

               ELgo is the appropriate emission limit from Subsection
                    (a)(1) for combustion of natural gas or distillate oil,
                    ng/J (lbs/million BTU),

               Hgo  is the heat input from combustion of natural gas,
                    distillate oil and gaseous byproduct/waste, ng/J
                    (lbs/million BTU),

               ELro is the appropriate emission limit from Subsection
                    (a)(2) for combustion of residual oil, ng/J
                    (lbs/million BTU),

               Hro  is the heat input from combustion of residual oil
                    and/or liquid byproducts/waste,

               ELc  is the appropriate emission limit from Subsection
                    (a)(3) for combustion of coal, and

               Hc   is the heat input from combustion of coal.

               (f)  Any owner or operator of an affected facility which
          combusts byproduct/waste with either natural gas or oil may
          petition the Administrator within 180 days of the initial startup
          of the affected facility to establish a nitrogen oxides emission
          limit which shall apply specifically to the affected  facility
          when the byproduct/waste is combusted.  The petition shall
          include sufficient and appropriate data, as determined by the
          Administrator, such as nitrogen oxides emissions from the
          affected facility, waste composition (including nitrogen
          content), and combustion conditions to allow the Administrator to
          confirm that the affected facility is unable to comply with the
          emission limits in Section (e) of this rule and to determine the
          appropriate emission limit for the affected facility.

                    (1)  Any owner or operator of an affected facility
               petitioning for a facility-specific nitrogen oxides emission
               limit pursuant to this rule shall:

                         (i)  Demonstrate compliance with the emission
                    limits for natural gas and distillate oil in Subsection
                    (a)(1) or for residual oil in Subsection (a)(2) of this
                    rule, as appropriate, by conducting a 30-day
                    performance test as provided in Rule 260.46b(e).
                    During the performance test only natural gas,
                    distillate oil, or residual oil shall be combusted in
                    the affected facility; and

                         (ii) Demonstrate that the affected facility is
                    unable to comply with the emission limits for natural
                    gas and distillate oil in Subsection (a)(1) or for
                    residual oil in Subsection (a)(2) of this rule, as
                    appropriate, when gaseous or liquid byproduct/ waste is
                    combusted in the affected facility under the same
                    conditions and using the same technological system of
                    emission reduction applied when demonstrating
                    compliance under Subsection (f)(1)(i) of this rule.

                    (2)  The nitrogen oxides emission limits for natural
               gas or distillate oil in Subsection (a)(1) or for residual
               oil in Subsection (a)(2) of this rule, as appropriate, shall
               be applicable to the affected facility until and unless the
               petition is approved by the Admin-istrator.  If the petition
               is approved by the Administrator, a facility-specific
               nitrogen oxides emission limit will be established at the
               nitrogen oxides emission level achievable when the affected
               facility is combusting oil, natural gas and byproduct/waste
               in a manner which the Administrator determines to be
               consistent with minimizing nitrogen oxides emissions.

               (g)  Any owner or operator of an affected facility which
          combusts hazardous waste (as defined by 40 CFR Part 261 or 40 CFR
          Part 761) with natural gas or oil may petition the Administrator
          within 180 days of the initial startup of the affected facility
          for a waiver from compliance with the nitrogen oxides emission
          limit which applies specifically to that affected facility.  The
          petition must include sufficient and appropriate data, as
          determined by the Administrator, on nitrogen oxide emissions from
          the affected facility, waste destruction efficiencies, waste
          composition (including nitrogen content), the quantity of
          specific wastes to be combusted and combustion conditions to
          allow the Administrator to determine if the affected facility is
          able to comply with the nitrogen oxides emission limits required
          by this rule.  The owner or operator of the affected facility
          shall demonstrate that when hazardous waste is combusted in the
          affected facility, thermal destruction efficiency requirements
          for hazardous waste specified in an applicable federally
          enforceable requirement preclude compliance with the nitrogen
          oxides emission limits of this rule.  The nitrogen oxides
          emission limits for natural gas or distillate oil in Subsection
          (a)(1) or for residual oil in Subsection (a)(2) of this rule, as
          appropriate, are applicable to the affected facility until and
          unless the petition is approved by the Administrator.  [See 40
          CFR 761.70 for regulations applicable to the incineration of
          materials containing polychlorinated biphenyls (PBC's)].

               (h)  The nitrogen oxide standards under this rule apply at
          all times including periods of startup, shutdown or malfunction.

               (i)  [RESERVED]

               (j)  Compliance with the emission limits under this rule is
          determined on a 24-hour average basis for the initial performance
          test and on a 3-hour average basis for subsequent performance
          tests for any affected facilities that:  (Effective 9-21-93)

                    (1)  Combust, alone or in combination, only natural
               gas, distillate oil, or residual oil with a nitrogen content
               of 0.30 weight percent or less;

                    (2)  Have a combined annual capacity factor of 10
               percent or less for natural gas, distillate oil, and
               residual oil with a nitrogen content of 0.30 weight percent
               or less; and

                    (3)  Are subject to a federally enforceable requirement
               limiting operation of the affected facility to the firing of
               natural gas, distillate oil, and/or residual oil with a
               nitrogen content of 0.30 weight percent or less and limiting
               operation of the affected facility to a combined annual
               capacity factor of 10 percent or less for natural gas,
               distillate oil, and residual oil and a nitrogen content of
               0.30 weight percent or less.

               (k)  Affected facilities that meet the criteria described in
          Subsections (j)(1), (2), and (3) of this rule, and that have a
          heat input capacity of 73 MW (250 million BTU/hour) or less, are
          not subject to the nitrogen oxides emission limits under this
          rule.  (Effective 9-21-93)


               RULE 260.45b.  COMPLIANCE AND PERFORMANCE TEST
                              METHODS AND PROCEDURES FOR SULFUR
                              DIOXIDE (Rev. Effective 9-21-93)

               (a)  The sulfur dioxide emission standards under Rule
          260.42b apply at all times.

               (b)  In conducting the performance tests required under Rule
          260.8, the owner or operator shall use the methods and procedures
          in Appendix A of this Regulation or the method and procedures as
          specified in this rule, except as provided in Rule 260.8(b).
          Rule 260.8(f) does not apply to this subpart.  The 30-day notice
          required in Rule 260.8(d) applies only to the initial performance
          test unless otherwise specified by the Control Officer.

               (c)  The owner or operator of an affected facility shall
          conduct performance tests to determine compliance with the
          percent of potential sulfur dioxide emission rate (% Ps) and the
          sulfur dioxide emission rate (Es) pursuant to Rule 260.42b
          following the procedures listed below, except as provided under
          Section (d) of this rule.

                    (1)  The initial performance test shall be conducted
               over the first 30 consecutive operating days of the steam
               generating unit.  Compliance with the sulfur dioxide
               standards shall be determined using one-hour averages where
               an exceedance averaged over any hour is a violation.  The
               first operating day included in the initial performance test
               shall be scheduled within 30 days after achieving the
               maximum production rate at which the affected facility will
               be operated, but not later than 180 days after initial
               startup of the facility.

                    (2)  If only coal or only oil is combusted, the
               following procedures are used:

                         (i)  The procedures in Method 19 are used to
                    determine the hourly sulfur dioxide emission rate (Eho)
                    and the 30-day average emission rate (Eao).  The hourly
                    averages used to compute the 30-day averages are
                    obtained from the continuous emission monitoring system
                    of Rule 260.47b(a) or (b).

                         (ii) The percent of potential sulfur dioxide
                    emission rate (% Ps) emitted to the atmosphere is
                    computed using the following formula:

                          % Ps = 100 (1 - % Rg/100) (1 - % Rf/100)

               where:

                    % Rg is the sulfur dioxide removal efficiency of the
                         control device as determined by Method 19, in
                         percent.

                    % Rf is the sulfur dioxide removal efficiency of fuel
                         pretreatment as determined by Method 19, in
                         percent.

                    (3)  If coal or oil is combusted with other fuels, the
               same procedures required in subsection (c)(2) of this rule
               are used, except as provided in the following:

                         (i)  Ehoo, the adjusted hourly sulfur dioxide
                    emission rate, is computed using the following formula:

                              Ehoo = [Eho - Ew (1 - Xk)]/Xk

               where:
                         Ehoo is the adjusted hourly sulfur dioxide
                              emission rate, ng/J (lbs/million BTU).

                         Eho  is the hourly sulfur dioxide emission rate
                              ng/J (lbs/million BTU).

                         Ew   is the sulfur dioxide concentration in fuels
                              other than coal and oil combusted in the
                              affected facility, as determined by the fuel
                              sampling and analysis procedures in Method
                              19, ng/J (lbs/million BTU).  The value Ew for
                              each fuel lot is used for each hourly average
                              during the time that the lot is being
                              combusted.

                         Xk   is the fraction of total heat input from fuel
                              combustion derived from coal, oil, or coal
                              and oil, as determined by applicable
                              procedures in Method 19.

                         (ii) To compute the percent of potential sulfur
                    dioxide emission rate (% Ps), an adjusted % Rg (% Rgo)
                    is computed from the adjusted Ehoo from Subsection
                    (b)(3)(i) of this rule and an adjusted average sulfur
                    dioxide inlet rate (Eaio) using the following formula:

                              % Rgo  =  100 (1.0 - Ehoo/Ehio)

                    The adjusted hourly sulfur dioxide inlet rate (Ehio) is
                    computed using the following formula:

                              Ehio  =  [Ehi - Ew(1 - Xk)]/Xk

               where:
                              Ehio is the adjusted hourly sulfur dioxide
                                   inlet rate, ng/J (lbs/million BTU).

                              Ehi  is the hourly sulfur dioxide inlet rate,
                                   ng/J (lbs/million BTU).

                    (4)  The owner or operator of an affected facility
               subject to Subsection (b)(3) of this rule does not have to
               measure parameters Ew or Xk if the owner or operator elects
               to assume that Xk = 1.0.  Owners or operators of affected
               facilities who assume Xk = 1.0 shall:

                         (i)  Determine % Ps following the procedures in
                    Subsection (c)(2) of this rule, and

                         (ii) Sulfur dioxide emissions (Es) are considered
                    to be in compliance with sulfur dioxide emission limits
                    under Rule 260.42b.

                    (5)  The owner or operator of an affected facility that
               qualifies under the provisions of Rule 260.42b(d) does not
               have to measure parameters Ew or Xk under Sub-section (b)(3)
               of this rule if the owner or operator of the affected
               facility elects to measure sulfur dioxide emission rates of
               the coal or oil following the fuel sampling and analysis
               procedures under Method 19.

               (d)  Except as provided in Section (j) of this rule, the
          owner or operator of an affected facility that combusts only low
          sulfur oil, has an annual capacity factor for oil of 10 percent
          (0.10) or less, and is subject to a federally enforceable
          requirement limiting operation of the affected facility to an
          annual capacity factor for oil of 10 percent (0.10) or less shall:
          (Rev. Effective 9-21-93)

                    (1)  Conduct the initial performance test over 24
               consecutive steam generating unit operating hours at full
               load;

                    (2)  Determine compliance with the standards after the
               initial performance test based on the arithmetic average of
               the hourly emissions data during each steam generating unit
               operating day if a continuous emission measurement system
               (CEMS) is used, or based on a daily average if Method 6B or
               fuel sampling and analysis procedures under Method 19 are
               used.

               (e)  The owner or operator of an affected facility subject
          to Rule 260.42b(d)(1) shall demonstrate the maximum design
          capacity of the steam generating unit by operating the facility
          at maximum capacity for 24-hours.  This demonstration will be
          made during the initial performance test and a subsequent
          demonstration may be requested at any other time.  If the 24-hour
          average firing rate for the affected facility is less than the
          maximum design capacity provided by the manufacturer of the
          affected facility, the 24-hour average firing rate shall be used
          to determine the capacity utilization rate for the affected
          facility, otherwise the maximum design capacity provided by the
          manufacturer is used.

               (f)  For the initial performance test required under Rule
          260.8, compliance with the sulfur dioxide emission limits and
          percent reduction requirements under Rule 260.42b is based on the
          average emission rates and the average percent reduction for
          sulfur dioxide for the first 30 consecutive steam generating unit
          operating days, except as provided under Section (d) of this
          rule.  The initial performance test is the only test for which at
          least 30 days prior notice is required unless otherwise specified
          by the Control Officer.  The initial performance test is to be
          scheduled so that the first steam generating unit operating day
          is completed within 30 days after achieving the maximum
          production rate at which the affected facility will be operated,
          but not later than 180 days after initial startup of the facil-
          ity.  The boiler load during the 30-day period does not have to
          be the maximum design load, but must be representative of future
          operating conditions and include at least one 24-hour period at
          full load.

               (g)  After the initial performance test required under Rule
          260.8, compliance with the sulfur dioxide emission limits and
          percent reduction requirements under Rule 260.42b is based on the
          average emission rates and the average percent reduction for
          sulfur dioxide for 30 successive steam generating unit operating
          days, except as provided under Section (d).  A separate
          performance test is completed at the end of each steam generating
          unit operating day after the initial performance test, and an
          hourly average emission rate and percent reduction for sulfur
          dioxide are calculated to show compliance with the standard.  An
          exceedance of the standard averaged over any given hour is a
          violation.

               (h)  Except as provided under Section (i) of this rule, the
          owner or operator of an affected facility shall use all valid
          sulfur dioxide emissions data in calculating % Ps and Eho under
          Section (c) of this rule whether or not the minimum emissions
          data requirements under Rule 260.46b are achieved.  All valid
          emission data, including valid sulfur dioxides emission data
          collected during periods of startup, shutdown and malfunction,
          shall be used in calculating % Ps and Eho pursuant to Section (c)
          of this rule.

               (i)  During periods of malfunction or maintenance of the
          sulfur dioxide control systems when oil is combusted as provided
          under Rule 260.42b(i), emission data are not used to calculate %
          Ps or Es under Rule 260.42b(a), (b), or (c), however the
          emissions data are used to determine compliance with the emission
          limit under Rule 260.42b(i).

               (j)  The owner or operator of an affected facility that
          combusts low sulfur oil is not subject to the compliance and
          performance testing requirements of this rule if the owner or
          operator obtains fuel receipts as described in Rule 260.49b(r).
          (Effective 9-21-93)





               RULE 260.46b.  COMPLIANCE AND PERFORMANCE METHODS
                              AND PROCEDURES FOR PARTICULATE MATTER
                              AND NITROGEN OXIDES  (Rev. Effective 9-21-93)

               (a)  The particulate matter emission standards and opacity
          limits under Rule 260.43b apply to all times except during
          periods of startup, shutdown, or malfunction.  The nitrogen
          oxides emission standards under Rule 260.44b apply at all times.

               (b)  Compliance with the particulate matter emission
          standards under Rule 260.43b shall be determined through
          performance testing as described in Section (d) of this rule.

               (c)  Compliance with the nitrogen oxides emission standards
          under Rule 260.44b shall be determined through performance
          testing under Sections (e) or (f) of this rule, or under Sections
          (g) and (h) of this rule, as applicable.  (Rev. Effective 9-21-
          93)

               (d)  To determine compliance with the particulate matter
          emission limits and opacity limits under Rule 260.43b, the owner
          or operator of an affected facility shall conduct an initial
          performance test as required under Rule 260.8 using the following
          procedures and reference methods:  (Rev. Effective 9-21-93)

                    (1)  Method 3B is used for gas analysis when applying
               Method 5 or Method 17.

                    (2)  Method 5, Method 5B or Method 17 shall be used to
               measure the concentration of particulate matter as follows:

                         (i)  Method 5 shall be used at affected facilities
                    without wet Flue Gas Desulfurization (FGD) systems; and

                         (ii) Method 17 may be used at facilities with or
                    without wet scrubber systems provided that the stack
                    gas temperature does not exceed a temperature of 160C
                    (320F).  The procedures of Sections 2.1 and 2.3 of
                    Method 5B may be used in Method 17 only if it is used
                    after a wet FGD system.  Do not use Method 17 after wet
                    FGD systems if the effluent is saturated or laden with
                    water droplets.

                         (iii)Method 5B is to be used only after wet FGD
                    systems.

                    (3)  Method 1 is used to select the sampling site and
               the number of traverse sampling points.  The sampling time
               for each run is at least 120 minutes and the minimum
               sampling volume is 1.7 dscm (60 dscf) except that smaller
               sampling times or volumes may be approved by the
               Administrator when necessitated by process variables or
               other factors.

                    (4)  For Method 5, the temperature of the sample gas in
               the probe and filter holder is monitored and is maintained
               at 160C (320F).

                    (5)  For determination of particulate emissions, the
               oxygen or carbon dioxide sample is obtained simultaneously
               with each run of Method 5, Method 5B or Method 17 by
               traversing the duct at the same sampling location.

                    (6)  For each run using Method 5, Method 5B or Method
               17, the emission rate expressed in ng/J heat input is
               determined using:

                         (i)  The oxygen or carbon dioxide measurements and
                    particulate matter measurements obtained under this
                    rule.

                         (ii) The dry basis Fe factor, and

                         (iii)The dry basis emission rate calculation
                    procedure contained in Method 19 (Appendix A).

                    (7)  Method 9 is used for determining the opacity of
               stack emissions.

               (e)  To determine compliance with the emission limits for
          nitrogen oxides required under Rule 260.44b, the owner or
          operator of an affected facility shall conduct the performance
          test as required under Rule 260.8b using the continuous system
          for monitoring nitrogen oxides under Rule 260.48(b).

                    (1)  For the initial compliance test, nitrogen oxides
               from the steam generating unit are monitored for 30
               successive steam generating unit operating days and the 60-
               minute average emission rate is used to determine compliance
               with the nitrogen oxides emission standards under Rule
               260.44b.  An exceedance of the standard averaged over any
               given hour is a violation.

                    (2)  Following the date on which the initial
               performance test is completed or is required to be completed
               under Rule 260.8 of this Regulation, whichever date comes
               first, the owner or operator of an affected facility which
               fires coal or which fires residual oil having a nitrogen
               content greater than 0.30 weight percent shall determine
               compliance with the nitrogen oxides emission standards under
               Rule 260.44b on a continuous basis through the use of a 60-
               minute average emission rate.  An exceedance of the standard
               averaged over any given hour is a violation.

                    (3)  Following the date on which the initial
               performance test is completed or is required to be completed
               under Rule 260.8 of this Regulation, whichever date comes
               first, the owner or operator of an affected facility which
               has a heat input capacity greater than 73 MW (250 million
               BTU/hour) and which fires natural gas, distillate oil, or
               residual oil having a nitrogen content of 0.30 weight
               percent or less shall determine compliance with the nitrogen
               oxides standards under Rule 260.44b on a continuous basis
               through the use of a 60-minute average emission rate.  An
               exceedance of the standard averaged over any given hour is a
               violation.

                    (4)  Following the date on which the initial
               performance test is completed or required to be completed
               under Rule 260.8 of this Regulation, whichever date comes
               first, the owner or operator of an affected facility which
               has a heat input capacity of 73 MW (250 million BTU/hour) or
               less and which fires natural gas, distillate oil, or
               residual oil having a nitrogen content of 0.30 weight
               percent or less shall upon request determine compliance with
               the nitrogen oxides standards under Rule 260.44b through the
               use of a 30-day performance test.  During periods when
               performance tests are not requested by the Control Officer,
               nitrogen oxides emissions data collected pursuant to Rule
               260.48b(g)(1) or 260.48b(g)(2) are used to calculate a 60-
               minute average emission rate on an hourly basis and to
               prepare excess emission reports.

                    (5)  If the owner or operator of an affected facility
               which fires residual oil does not sample and analyze the
               residual oil for nitrogen content, as specified in Rule
               260.49b(e), the requirements of Subsection (e)(3) of this
               rule apply and the provisions of Subsection (e)(4) of this
               rule are inapplicable.

               (f)  To determine compliance with the emission limit for
          nitrogen oxides required by Rule 260.44b(a)(4) for duct burners
          used in combined cycle systems, the owner or operator of an
          affected facility shall conduct the performance test required
          under Rule 260.8 using the nitrogen oxides and oxygen measurement
          procedures in 40 CFR Part 60 Appendix A, Method 20.  During the
          performance test, one sampling site shall be located as close as
          practical to the exhaust of the turbine, as provided by Section
          6.1.1 of Method 20.  A second sampling site shall be located at
          the outlet to the steam generating unit.  Measurements of
          nitrogen oxides and oxygen shall be taken at these two sampling
          sites simultaneously during the performance test.  The nitrogen
          oxides emission rate from the combined cycle system shall be
          calculated by subtracting the nitrogen oxides emission rate
          measured at the sampling site at the outlet from the turbine from
          the nitrogen oxides emission rate measured at the sampling site
          at the outlet from the steam generating unit.

               (g)  The owner or operator of an affected facility described
          in Rule 260.44b(j) or 260.44b(k) shall demonstrate the maximum
          heat input capacity of the steam generating unit by operating the
          facility at maximum capacity for 24 hours.  The owner or operator
          of an affected facility shall determine the maximum heat input
          capacity using the heat loss method described in Sections 5 and
          7.3 of the ASME Power Test Codes 4.1.  This demonstration of
          maximum heat input capacity shall be made during the initial
          performance test for affected facilities that meet the criteria
          of Rule 260.44b(j).  It shall be made within 60 days after
          achieving the maximum production rate at which the affected
          facility will be operated, but not later than 180 days after
          initial startup of each facility, for affected facilities meeting
          the criteria of Rule 260.44b(k).  Subsequent demonstrations maybe
          required by the Control Officer at any  other time.  If this
          demonstration indicates that the maximum heat input capacity of
          the affected facility is less than that stated by the
          manufacturer of the affected facility, the maximum heat input
          capacity determined during this demonstration shall be used to
          determine the capacity utilization rate for the affected
          facility.  Otherwise, the maximum heat input capacity provided by
          the manufacturer is used.  (Effective 9-21-93)

               (h)  The owner or operator of an affected facility described
          in Rule 260.44b(j) that has a heat input capacity greater than 73
          MW (250 million BTU/hour) shall:    (Effective 9-21-93)

                    (1)  Conduct an initial performance test as required
               under Rule 260.8 over a minimum of 24 consecutive steam
               generating unit operating hours at maximum heat input
               capacity to demonstrate compliance with the nitrogen oxides
               emission standards under Rule 260.44b using Method 7, 7A,
               7E, or other approved reference methods; and

                    (2)  Conduct subsequent performance tests once per
               calendar year or every 400 hours of operation (whichever
               comes first) to demonstrate compliance with the nitrogen
               oxides emission standards under Rule 260.44b over a minimum
               of 3 consecutive steam generating unit operating hours at
               maximum heat input capacity using Method 7, 7A, 7E, or other
               approved reference methods.


               RULE 260.47b.  EMISSION MONITORING FOR SULFUR
                              DIOXIDE   (Effective 3-14-89; Rev. Effective
                                                                  9-21-93)

               (a)  Except as provided in Sections (b) and (f) of this
          rule, the owner or operator of an affected facility subject to
          the sulfur dioxide standards under Rule 260.42b shall install,
          calibrate, maintain, and operate continuous emission monitoring
          system (CEMS) for measuring sulfur dioxide concentrations and
          either oxygen (O2) or carbon dioxide (CO2) concentrations and
          shall record the output of the systems.  The sulfur dioxide and
          either oxygen or carbon dioxide concentrations shall both be
          monitored at the inlet and outlet of the sulfur dioxide control
          device.  (Rev. Effective 9-21-93)

               (b)  As an alternative to operating CEMS as required under
          Section (a) of this rule, an owner or operator may elect to
          determine the average sulfur dioxide emissions and percent
          reduction by:  (Rev. Effective 9-21-93)

                    (1)  Collecting coal or oil samples in an as-fired
               condition at the inlet to the steam generating unit and
               analyzing them for sulfur and heat content according to
               Method 19.  Method 19 provides procedures for converting
               these measurements into the format to be used in calculating
               the average sulfur dioxide input rate, or

                    (2)  Measuring sulfur dioxide according to Method 6B at
               the inlet or outlet to the sulfur dioxide control system.
               An initial stratification test is required to verify the
               adequacy of the Method 6B sampling location.  The
               stratification test shall consist of three paired runs of a
               suitable sulfur dioxide and carbon dioxide measurement train
               operated at the candidate location and a second similar
               train operated according to the procedures in Section 3.2
               and the applicable procedures in Section 7 of Performance
               Specification 2.  Method 6B, Method 6A, or a combination of
               Method 6 and 3 or 3B or Methods 6C and 3A are suitable
               measurement techniques.  If Method 6B is used for the second
               train, sampling time and timer operation may be adjusted for
               the stratification test as long as an adequate sample volume
               is collected; however, both sampling trains are to be
               operated similarly.  For the location to be adequate for
               Method 6B 24-hour tests, the mean of the absolute difference
               between the three paired runs must be less than 10 percent.

                    (3)  A daily sulfur dioxide emission rate, ED, shall be
               determined using the procedure described in Method 6A,
               Section 7.6.2 (Equation 6A-8) and stated in ng/J
               (lbs/million BTU) heat input.

                    (4)  RESERVED

               (c)  The owner or operator of an affected facility shall
          obtain emission data for at least 75 percent of the operating
          hours in at least 22 out of 30 successive boiler operating days.
          If this minimum data requirement is not met with a single
          monitoring system, the owner or operator of the affected facility
          shall supplement the emission data with data collected with other
          monitoring systems as approved by the Administrator or the
          reference methods and procedures as described in Section (b) of
          this rule.

               (d)  The 1-hour average sulfur dioxide emission rates
          measured by the CEMS required by Section (a) of this rule and
          required under Rule 260.13(h) is expressed in ng/J or lbs/million
          BTU heat input and is used to calculate the average emission
          rates under Rule 260.42b.  Each 1-hour average sulfur dioxide
          emission rate must be based on more than 30 minutes of steam
          generating unit operation and include at least 2 data points with
          each representing a 15-minute period.  Hourly sulfur dioxide
          emission rates are not calculated if the affected facility is
          operated less than 30 minutes in a 1-hour period and are not
          counted toward determination of a steam generating unit operating
          day.

               (e)  The procedures under Rule 260.13 shall be followed for
          installation, evaluation, and operation of the CEMS.

                    (1)  All CEMS shall be operated in accordance with the
               applicable procedures under Performance Specification 1, 2,
               and 3 (Appendix B).

                    (2)  Quarterly accuracy determinations and daily
               calibration drift tests shall be performed in accordance
               with Procedure 1 (Appendix F).

                    (3)  For affected facilities combusting coal or oil,
               alone or in combination with other fuels, the span value of
               the sulfur dioxide CEMS at the inlet to the sulfur dioxide
               control device is 125 percent of the maximum estimated
               hourly potential sulfur dioxide emissions of the fuel
               combusted, and the span value of the CEMS at the outlet to
               the sulfur dioxide control device is 50 percent of the
               maximum estimated hourly potential sulfur dioxide emissions
               of the fuel combusted.

               (f)  The owner or operator of an affected facility that
          combusts low sulfur oil is not subject to the emission monitoring
          requirements of this rule if the owner or operator obtains fuel
          receipts as described in Rule 260.49b(r).  (Effective 9-21-93)
               
               
               RULE 260.48b.  EMISSION MONITORING FOR PARTICULATE
                              MATTER AND NITROGEN OXIDES
                              (Rev. Effective 9-21-93)

               (a)  The owner or operator of an affected facility subject
          to the opacity standard under Rule 260.43b shall install,
          calibrate, maintain and operate a continuous monitoring system
          for measuring the opacity of emissions discharged to the
          atmosphere and record the output of the system.

               (b)  Except as provided in Sections (g), (h) and (i) of this
          rule, the owner or operator of an affected facility subject to
          the nitrogen oxides standard of Rule 260.44b shall install,
          calibrate, maintain, and operate a continuous monitoring system
          for measuring nitrogen oxides emissions discharged to the
          atmosphere and record the output of the system.  (Rev. Effective
          9-21-93)

               (c)  The continuous monitoring systems required under
          Section (b) of this rule shall be operated and data recorded
          during all periods of operation of the affected facility except
          for continuous monitoring system breakdowns, and repairs.  Data
          is recorded during calibration checks, and zero and span
          adjustments.

               (d)  The 1-hour average nitrogen oxides emissions rates
          measured by the continuous nitrogen oxides monitor required by
          Section (b) of this rule and required under Rule 260.13(h) shall
          be expressed in ng/J or lbs/million BTU heat input and shall be
          used to calculate the average emission rates under Rule 260.44b.
          The 1-hour averages shall be calculated using the data points
          required under Rule 260.13(b).  At least two data points must be
          used to calculate each 1-hour average.

               (e)  The procedures under Rule 260.13 shall be followed for
          installation, evaluation, and operation of the continuous
          monitoring systems.

                    (1)  For affected facilities combusting coal, wood, or
               municipal-type solid waste, the span value for continuous
               monitoring system for measuring opacity shall be between 60
               and 80 percent.

                    (2)  For affected facilities combusting coal, oil, or
               natural gas, the span value for nitrogen oxides is
               determined as follows:

                                                       SPAN VALUES FOR
                    FUEL                               NITROGEN OXIDES (ppm)

                    Natural gas                             500
                    Oil                                     500
                    Coal                                  1,000
                    Combination                 500 (x + y)  +  1,000z

               where:

                    x is the fraction of total heat input derived from
                      natural gas,

                    y is the fraction of total heat input derived from oil,
                      and

                    z is the fraction of total heat input derived from
                      coal.

                    (3)  All span values computed under Subsection (e)(2)
               of this rule for combusting combinations of regulated fuels
               are rounded to the nearest 500 ppm.

               (f)  When nitrogen oxides emission data are not obtained
          because of continuous monitoring system breakdowns, repairs,
          calibration checks and zero and span adjustments, emission data
          will be obtained by using standby monitoring systems, Method 7,
          Method 7A, or other approved reference methods to provide
          emission data for a minimum of 75 percent of the operating hours
          in each steam generating unit operating day, in at least 22 out
          of 30 successive steam generating unit operating days.

               (g)  The owner or operator of an affected facility which has
          a heat input capacity of 73 MW (250 million BTU/hour) or less,
          and which has an annual capacity factor for residual oil having a
          nitrogen content of 0.30 weight percent or less, natural gas,
          distillate oil, or any mixture of these fuels greater than 10
          percent (0.10) shall:

                    (1)  Comply with the provisions of Sections (b), (c),
               (d), (e)(2), (e)(3), and (f) of this rule, or

                    (2)  Monitor steam generating unit operating conditions
               and predict nitrogen oxides emission rates as specified in a
               plan submitted pursuant to Rule 260.49b(c).

               (h)  The owner or operator of an affected facility which is
          subject to the nitrogen oxides standards of Rule 260.44b(a)(4) is
          not required to install or operate a continuous monitoring system
          to measure nitrogen oxides emissions.

               (i)  The owner or operator of an affected facility described
          in Rules 260.44b(j) or 260.44b(k) is not required to install or
          operate a continuous monitoring system for measuring nitrogen
          oxides emissions.



               RULE 260.49b.  REPORTING AND RECORDKEEPING REQUIRE-
                              MENTS   (Rev. Effective 9-21-93)

               (a)  The owner or operator of each affected facility shall
          submit notification of the date of initial startup, as provided
          by Rule 260.7.  This notification shall include:
          (Rev. Effective 9-21-93)

                    (1)  The design heat input capacity of the affected
               facility and identification of the fuels to be combusted in
               the affected facility.

                    (2)  If applicable, a copy of any federally enforceable
               requirement that limits the annual capacity factor for any
               fuel or mixture of fuels under Rules 260.42b(d)(1),
               260.42b(f)(1), 260.43b(a)(2), 260.43b(a)(3)(iii),
               260.43b(c)(2)(ii), 260.43b(d)(2)(iii), 260.44b(c),
               260.44b(d), 260.44b(e), 260.44b(i), 260.44b(j), 260.44b(k),
               260.45b(d), 260.46b(g), 260.46b(h), or 260.48b(i).

                    (3)  The annual capacity factor at which the owner or
               operator anticipates operating the facility based on all
               fuels fired and based on each individual fuel fired, and

                    (4)  Notification that an emerging technology will be
               used for controlling emissions of sulfur dioxide.  The
               Administrator will examine the description of the emerging
               technology and will determine whether the technology
               qualifies as an emerging technology.  In making this
               determination, the Administrator may require the owner or
               operator of the affected facility to submit additional
               information concerning the control device.  The affected
               facility is subject to the provisions of Rule 260.42b(a)
               unless and until this determination is made by the
               Administrator.

               (b)  The owner or operator of each affected facility subject
          to the sulfur dioxide, particulate matter and nitrogen oxides
          emission limits under Rule 260.42b, 260.43b, and 260.44b, shall
          submit to the Control Officer the performance test data from the
          initial performance test and the performance evaluation of the
          CEMS using the applicable performance specifications in Appendix
          B.  The owner or operator of each affected facility described in
          Rules 260.44b(j) or 260.44b(k) shall submit to the Control
          Officer the maximum heat input capacity data from the
          demonstration of the maximum heat input capacity of the affected
          facility.  (Rev. Effective 9-21-93)

               (c)  The owner or operator of each affected facility subject
          to the nitrogen oxides standard of Rule 260.44b who seeks to
          demonstrate compliance with those standards through the
          monitoring of steam generating unit operating conditions under
          the provisions of Rule 260.48b (g)(2) shall submit to the Control
          Officer for approval a plan which identifies the operating
          conditions to be monitored under Rule 260.48b(g)(2) and the
          records to be maintained under Rule 260.49b(j).  This plan shall
          be submitted to the Control Officer for approval within 360 days
          of the initial startup of the affected facility.  The plan shall:

                    (1)  Identify the specific operating conditions to be
               monitored and the relationship between these operating
               conditions and nitrogen oxides emission rates (i.e., ng/J or
               lbs/million BTU heat input).  Steam generating unit
               operating conditions include, but are not limited to, degree
               of staged combustion (i.e., the ratio of primary air to
               secondary and/or tertiary air) and the level of excess air
               (i.e., flue gas oxygen level);

                    (2)  Include the data and information which the owner
               or operator used to identify the relationship between
               nitrogen oxides emission rates and these operating
               conditions;

                    (3)  Identify how these operating conditions, including
               steam generating unit load, will be monitored under Rule
               260.48b(g) on an hourly basis by the owner or operator
               during the period of operation of the affected facility; the
               quality assurance procedures or practices that will be
               employed to ensure that the data generated by monitoring
               these operating conditions will be representative and
               accurate; and the type and format of the records of these
               operating conditions, including steam generating unit load
               that will be maintained by the owner or operator under Rule
               260.49b(j).

                    If the plan is approved, the owner or operator shall
               maintain records of predicted nitrogen oxide emission rates
               and the monitored operating conditions, including steam
               generating unit load, identified in the plan.

               (d)  The owner or operator of an affected facility shall
          record and maintain records of the amounts of each fuel combusted
          during each day and calculate the annual capacity factor
          individually for coal, distillate oil, residual oil, natural gas,
          wood and municipal-type solid waste for each calendar quarter.
          The annual capacity factor is determined on a 12-month rolling
          average basis with a new annual capacity factor calculated at the
          end of each calendar month.

               (e)  For an affected facility that combusts residual oil and
          meets the criteria under Rules  260.44b(j), 260.44b(k), or
          260.46b(e)(4), the owner or operator shall maintain records of
          the nitrogen content of the oil combusted in the affected
          facility and calculate the average fuel nitrogen content on a per
          calendar quarter basis.  The nitrogen content shall be determined
          using ASTM Method D3431-80, Test Method for Trace Nitrogen in
          Liquid Petroleum Hydrocarbons, (IBR - see 40 CFR Section 60.17),
          or fuel specification data obtained from fuel suppliers.  If
          residual oil blends are being combusted, fuel nitrogen
          specifications may be prorated based on the ratio of residual
          oils of different nitrogen content in the fuel blend.  (Rev.
          Effective 9-21-93)

               (f)  For facilities subject to the opacity standard under
          Rule 260.43b, the owner or operator shall maintain records of
          opacity.

               (g)  Except as provided under Section (p) of this rule, the
          owner or operator of an affected facility subject to the nitrogen
          oxides standards under Rule 260.44b shall maintain records of the
          following information for each steam generating unit operating
          day:  (Rev. Effective 9-21-93)

                    (1)  Calendar date.

                    (2)  The average hourly nitrogen oxides emission rates
               (expressed as NO2) (ng/J or lbs/million BTU heat input)
               measured or predicted.

                    (3)  RESERVED

                    (4)  Identification of the steam generating unit
               operating days when any calculated hourly average nitrogen
               oxides emission rates are in excess of the nitrogen oxides
               emissions standards under Rule 260.44b, with the reasons for
               such excess as well as a description of corrective actions
               taken.

                    (5)  Identification of the steam generating unit
               operating days for which pollutant data have not been
               obtained, including reasons for not obtaining sufficient
               data and a description of corrective actions taken.

                    (6)  Identification of the times when emission data
               have been excluded from the calculation of average emission
               rates and the reasons for excluding data.

                    (7)  Identification of "F" factor used for
               calculations, method of determination, and type of fuel
               combusted.

                    (8)  Identification of the times when the pollutant
               concentration exceeded full span of the continuous
               monitoring system.

                    (9)  Description of any modifications to the continuous
               monitoring system that could affect the ability of the
               continuous monitoring system to comply with Performance
               Specifications 2 or 3.

                    (10) Results of daily CEMS drift tests and quarterly
               accuracy assessments as required under Appendix F, Procedure
               1.

               (h)  The owner or operator of any affected facility in any
          category listed below in Subsection (h)(1) or (h)(2) of this rule
          is required to submit excess emission reports for any calendar
          quarter during which there are excess emissions from the affected
          facility.  If there are no excess emissions during the calendar
          quarter, the owner or operator shall submit a report semiannually
          stating that no excess emissions occurred during the semiannual
          reporting period.

                    (1)  Any affected facility subject to the opacity
               standards under Rule 260.43b(e) or to the operating
               parameter monitoring requirements under Rule 260.13(i)(1).

                    (2)  Any affected facility that is subject to the
               nitrogen oxides standard of Rule 260.44b and that:

                         (i)  Combusts natural gas, distillate oil, or
                    residual oil with a nitrogen content of 0.3 weight
                    percent or less, or

                         (ii) Has a heat input capacity of 73 MW (250
                    million BTU/hour) or less and is required to monitor
                    nitrogen oxides emissions on a continuous basis under
                    Rule 260.48b(g)(1) or steam generating unit operating
                    conditions under Rule 260.48b(g)(2).

                    (3)  For the purpose of Rule 260.43b, excess emissions
               are defined as all 6-minute periods during which the average
               opacity exceeds the opacity standards under Rule 260.43b(f).

                    (4)  For the purposes of Rule 260.48b(g)(1), excess
               emissions are defined as any 60-minute average nitrogen
               oxides emission rate, as determined under Rule 260.46b(e),
               which exceeds the applicable emission limits in Rule
               260.44b.

               (i)  The owner or operator of any affected facility subject
          to the continuous monitoring requirements for nitrogen oxides
          under Rule 260.48b shall submit a quarterly report containing the
          information recorded under Section (g) of this rule.  All
          quarterly reports shall be postmarked by the 30th day following
          the end of each calendar quarter.

               (j)  The owner or operator of any affected facility subject
          to the sulfur dioxide standards under Rule 260.42b shall submit
          written reports to the Administrator for every calendar quarter.
          All quarterly reports shall be postmarked by the 30th day
          following the end of each calendar quarter.

               (k)  For each affected facility subject to compliance and
          performance testing requirements of Rule 260.45b and the
          reporting requirement in Section (j) of this rule, the following
          information shall be reported to the Administrator:

                    (1)  Calendar dates covered in the reporting period.

                    (2)  Each 30-day average sulfur dioxide emission rate
               (ng/J or lbs/million BTU heat input) measured during the
               reporting period, ending with the last 30-day period in the
               quarter; reasons for noncompliance with the emission
               standards; and a description of corrective actions taken.

                    (3)  Each 30-day average percent reduction in sulfur
               dioxide emissions calculated during the reporting period,
               ending with the last 30-day period in the quarter; reasons
               for noncompliance with the emission standards; and a
               description of corrective actions taken.

                    (4)  Identification of the steam generating unit
               operating days that coal or oil was combusted and for which
               sulfur dioxide or diluent (oxygen or carbon dioxide) data
               have been obtained by an approved method for at least 75
               percent of the operating hours in the steam generating unit
               operating day; justification for not obtaining sufficient
               data; and description of corrective action taken.

                    (5)  Identification of the times when emissions data
               have been excluded from the calculation of average emission
               rates; justification for excluding data; and description of
               corrective action taken if data have been excluded for
               periods other than those during which coal or oil were not
               combusted in the steam generating unit.

                    (6)  Identification of "F" factor used for
               calculations, method of determination, and type of fuel
               combusted.

                    (7)  Identification of times when hourly averages have
               been obtained based on manual sampling methods.

                    (8)  Identification of the times when the pollutant
               concentration exceeded full span of the CEMS.

                    (9)  Description of any modifications to the CEMS that
               could affect the ability of the CEMS to comply with
               Performance Specification 2 or 3.

                    (10) Results of daily CEMS drift tests and quarterly
               accuracy assessments as required under Appendix F, Procedure
               1.

                    (11) The annual capacity factor of each unit fired as
               provided under Section (d) of this rule.

               (l)  For each affected facility subject to the compliance
          and performance testing requirements of Rule 260.45b(d) and the
          reporting requirements of Section (j) of this rule, the following
          information shall be reported to the Administrator:

                    (1)  Calendar dates when the facility was in operation
               during the reporting period;

                    (2)  The 24-hour average sulfur dioxide emission rate
               measured for each steam generating unit operating day during
               the reporting period that coal or oil was combusted, ending
               in the last 24-hour period in the quarter; reasons for
               noncompliance with the emission standards; and a description
               of corrective actions taken;

                    (3)  Identification of the steam generating unit
               operating days that coal or oil was combusted for which
               sulfur dioxide or diluent (oxygen or carbon dioxide) data
               have not been obtained by an approved method for at least 75
               percent of the operating hours; justification for not
               obtaining sufficient data; and description of corrective
               action taken.

                    (4)  Identification of the times when emissions data
               have been excluded from the calculation of average emission
               rates; justification for excluding data; and description of
               corrective action taken if data have been excluded for
               periods other than those during which coal or oil were not
               combusted in the steam generating unit.

                    (5)  Identification of "F" factor used for
               calculations, method of determination, and type of fuel
               combusted.

                    (6)  Identification of times when hourly averages have
               been obtained based on manual sampling methods.

                    (7)  Identification of the times when the pollutant
               concentration exceeded full span of the CEMS.

                    (8)  Description of any modifications to the CEMS which
               could affect the ability of the CEMS to comply with
               Performance Specification 2 or 3.

                    (9)  Results of daily CEMS drift tests and quarterly
               accuracy assessments as required under Appendix F, Procedure
               1.

               (m)  For each affected facility subject to the sulfur
          dioxide standards under Rule 260.42b for which the minimum amount
          of data required under Rule 260.47b(f) were not obtained during a
          calendar quarter, the following information is reported to the
          Administrator in addition to that required under Section (k) of
          this rule.

                    (1)  The number of hourly averages available for outlet
               emission rates and inlet emission rates.

                    (2)  The standard deviation of hourly averages for
               outlet emission rates and inlet emission rates, as
               determined in Method 19, Section 7.

                    (3)  The lower confidence limit for the mean outlet
               emission rate and the upper confidence limit for the mean
               inlet emission rate, as calculated in Method 19, Section 7.

                    (4)  The ratio of the lower confidence limit for the
               mean outlet emission rate and the allowable emission rate,
               as determined in Method 19, Section 7.

               (n)  If a percent removal efficiency by fuel pretreatment
          (i.e., % Rf) is used to determine the overall percent reduction
          (i.e., % Ro) under Rule 260.45b, the owner or operator of the
          affected facility shall submit a signed statement with the
          quarterly report:

                    (1)  Indicating what removal efficiency by fuel
               pretreatment (i.e., % Rf) was credited for the calendar
               quarter;

                    (2)  Listing the quantity, heat content, and date each
               pretreated fuel shipment was received during the previous
               calendar quarter; the name and location of the fuel
               pretreatment facility; and the total quantity and total heat
               content of all fuels received at the affected facility
               during the previous calendar quarter;

                    (3)  Documenting the transport of the fuel from the
               fuel pretreatment facility to the steam generating unit.

                    (4)  Including a signed statement from the owner or
               operator of the fuel pretreatment facility certifying that
               the percent removal efficiency achieved by fuel pretreatment
               was determined in accordance with the provisions of Method
               19 (Appendix A) and listing the heat content and sulfur
               content of each fuel before and after fuel pretreatment.

               (o)  All records required under this rule shall be
          maintained by the owner or operator of the affected facility for
          a period of 2 years following the date of such record.

               (p)  The owner or operator of an affected facility described
          in Rules 260.44b(j) or 260.44b(k) shall maintain records of the
          following information for each steam generating unit operating
          day:  (Effective 9-21-93)

                    (1)  Calendar date,

                    (2)  The number of hours of operation, and

                    (3)  A record of the hourly steam load.

               (q)  The owner or operator of an affected facility described
          in Rules 260.44b(j) or 260.44b(k) shall submit to the Control
          Officer on a quarterly basis:  (Effective 9-21-93)

                    (1)  The annual capacity factor over the previous 12
               months,

                    (2)  The average fuel nitrogen content during the
               quarter, if residual oil was fired; and

                    (3)  If the affected facility meets the criteria
               described in Rule 260.44b(j), the results of any nitrogen
               oxides emission tests required during the quarter, the hours
               of operation during the quarter, and the hours of operation
               since the last nitrogen oxides emission test.

               (r)  The owner or operator of an affected facility who
          elects to demonstrate that the affected facility combusts only
          low sulfur oil under Rule 260.42b(j)(2) shall obtain and maintain
          at the affected facility fuel receipts from the fuel supplier
          which certify that the oil meets the definition of  distillate
          oil as defined in Rule 260.41b.  For the purposes of this rule,
          the oil need not meet the fuel nitrogen content specification in
          the definition of distillate oil.  Quarterly reports shall be
          submitted to the Control Officer certifying that only low sulfur
          oil meeting this definition was combusted in the affected
          facility during the preceding quarter.  (Effective 9-21-93)