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Texas SIP: 30 TAC 117.131-117.149: Utility Electric Generation in East and Central Texas; SIP effective 2001.04.16

Regulatory Text: 
Texas Chapter 117 (Reg 7) - Control of Air Pollution from Nitrogen Compounds

SUBCHAPTER B : COMBUSTION AT EXISTING MAJOR SOURCES

DIVISION 2 :  UTILITY ELECTRIC GENERATION IN EAST AND CENTRAL TEXAS

Outline: 
§117.131.  Applicability.
§117.133.  Exemptions.
§117.134.  Gas-Fired Steam Generation.
§117.135.  Emission Specifications.
§117.138.  System Cap.
§117.141.  Initial Demonstration of Compliance.
§117.143.  Continuous Demonstration of Compliance.
§117.145.  Final Control Plan Procedures.
§117.147.  Revision of Final Control Plan.
§117.149.  Notification, Recordkeeping, and Reporting Requirements.


§117.131.  Applicability.
As adopted by TNRCC April 19, 2000, effective May 11, 2000

(Approved by EPA March 16, 2001 (66 FR 15195) effective April 16, 2001)

     The provisions of this division shall apply to each utility electric power boiler and stationary gas turbine that:

          (1)  generates electric energy for compensation;

          (2)  is owned or operated by an electric cooperative, independent power producer, municipality, river authority, or public utility, or any of its successors;

          (3)  was placed into service before December 31, 1995; and

          (4)  is located in Atascosa, Bastrop, Bexar, Brazos, Calhoun, Cherokee, Fannin, Fayette, Freestone, Goliad, Gregg, Grimes, Harrison, Henderson, Hood, Hunt, Lamar, Limestone, Marion, McLennan, Milam, Morris, Nueces, Parker, Red River, Robertson, Rusk, Titus, Travis, Victoria, or Wharton County.

************* end tx 117.131 adopted April 19, 2000 ****************b351**

§117.133.  Exemptions.
As adopted by TNRCC April 19, 2000, effective May 11, 2000

(Approved by EPA March 16, 2001 (66 FR 15195) effective April 16, 2001)

     The provisions of this division, except as may be specified in §117.143 and §117.149 of this title (relating to Continuous Demonstration of Compliance; and Notification, Recordkeeping, and Reporting Requirements), do not apply to:

          (1)  utility electric power boilers or stationary gas turbines if the annual heat input does not exceed 2.2 (1011) British thermal units per year, averaged over the three most recent calendar years;
          (2)  stationary gas turbines and auxiliary boilers which are:

               (A)  used solely to power other units during start-ups; or

               (B)  demonstrated to operate no more than an average of 10% of the hours of the year, averaged over the three most recent calendar years, and no more than 20% of the hours in a single calendar year; and

          (3)  each unit that generates electric energy primarily for internal use but that, averaged over the three most recent calendar years, sold less than one-third of its potential electrical output capacity to a utility power distribution system.


************* end tx 117.133 adopted April 19, 2000 ****************b351**

§117.134.  Gas-Fired Steam Generation.
As adopted by TNRCC April 19, 2000, effective May 11, 2000

(Approved by EPA March 16, 2001 (66 FR 15195) effective April 16, 2001)

     (a)  Subsections (b), (c), and (d) of this section (emission specifications adopted by the Texas Air Control Board in 1972) apply in Fannin, Hood, and Palo Pinto Counties.  This section shall no longer apply in Fannin and Hood Counties after the applicable final compliance date specified in §117.512 of this title (relating to Compliance Schedule for Utility Electric Generation in East and Central Texas).

     (b)  No person shall allow emissions of nitrogen oxides (NOx), calculated as nitrogen dioxide (NO2), from any "opposed-fired" steam generating unit of more than 600,000 pounds per hour (lbs/hr) maximum continuous steam capacity to exceed 0.7 pound per million British thermal units (lb/MMBtu) heat input, maximum two-hour average, at maximum steam capacity.  An "opposed-fired" steam generating unit is defined as a unit having burners installed on two opposite vertical firebox surfaces.

     (c)  No person shall allow emissions of NOx, calculated as NO2, from any "front-fired" steam generating unit of more than 600,000 lbs/hr maximum continuous steam capacity to exceed 0.5 lb/MMBtu heat input, maximum two-hour average, at maximum steam capacity.  A "front-fired" steam generating unit is defined as a unit having all burners installed in a geometric array on one vertical firebox surface.

     (d)  No person shall allow emissions of NOx, calculated as NO2, from any "tangential-fired" steam generating unit of more than 600,000 lbs/hr maximum continuous steam capacity to exceed 0.25 lb/MMBtu heat input, maximum two-hour average, at maximum steam capacity.  A "tangential-fired" steam generating unit is defined as a unit having burners installed on all corners of the unit at various elevations.

     (e)  Existing gas-fired steam generating units of more than 600,000 lbs/hour, but less than 1,100,000 lbs/hr, maximum continuous steam capacity are exempt from the provisions of this section, provided the total steam generated from the unit during any one calendar year does not exceed 30% of the product of the maximum continuous steam capacity of the unit times the number of hours in a year.  Written records of the amount of steam generated for each day's operation shall be made on a daily basis and maintained for at least three years from the date of each entry.  Such records shall be made available upon request to representatives of the executive director, EPA, or any local air pollution control agency having jurisdiction.

************* end tx 117.134 adopted April 19, 2000 ****************b351**

§117.135.  Emission Specifications.
As adopted by TNRCC April 19, 2000, effective May 11, 2000

(Approved by EPA March 16, 2001 (66 FR 15195) effective April 16, 2001)

     In accordance with the compliance schedule in §117.512 of this title (relating to Compliance Schedule for Utility Electric Generation in East and Central Texas), the owner or operator of each utility electric power boiler or stationary gas turbine shall ensure that emissions of nitrogen oxide (NOx) do not exceed the following rates, in pound per million British thermal unit (lb/MMBtu) heat input on an annual (calendar year) average:

          (1)  electric power boilers:

               (A)  gas-fired, 0.14;

               (B)  coal-fired, 0.165;

          (2)  stationary gas turbines:

               (A)  subject to TUC, §39.264 (except units designated in accordance with TUC, §39.264(i)), 0.14;

               (B)  not subject to TUC, §39.264, 0.15 (or alternatively, 42 parts per million by volume (ppmv) NOx, adjusted to 15% oxygen (dry basis)); and

               (C)  units designated in accordance with TUC, §39.264(i), 0.15 (or alternatively, 42 ppmv NOx, adjusted to 15% oxygen (dry basis)).


************* end tx 117.135 adopted April 19, 2000 ****************b351**

§117.138.  System Cap.
As adopted by TNRCC April 19, 2000, effective May 11, 2000

(Approved by EPA March 16, 2001 (66 FR 15195) effective April 16, 2001)

     (a)  An owner or operator may achieve compliance with the nitrogen oxides (NOx) emission limits of §117.135 of this title (relating to Emission Specifications) by achieving equivalent NOx emission reductions obtained by compliance with a system cap emission limitation in accordance with the requirements of this section.

     (b)  Each unit within an electric power generating system, as defined in §117.10(11)(B) of this title (relating to Definitions), that would otherwise be subject to the NOx emission limits of §117.135 of this title must be included in the system cap.

     (c)  The annual average emission cap shall be calculated using the following equation.


NOx annual average emission cap (tons/year)

    = Sum from i=1 to N of {(Hi x Ri)/2000}


Where:

     i     =     Each unit in the electric power generating system
     N     =     The total number of units in the emission cap
     Hi     =     The average of the annual heat input for each unit in the emission cap, in million British thermal units (Btu) per year, as certified to the executive director, for 1996, 1997, and 1998
     Ri     =     The emission limit of §117.135 of this title

     (d)  The NOx emissions monitoring required by §117.143 of this title (relating to Continuous Demonstration of Compliance) for each unit in the system cap shall be used to demonstrate continuous compliance with the system cap.

     (e)  For each operating unit, the owner or operator shall use one of the following methods to provide substitute emissions compliance data during periods when the NOx monitor is off-line:

          (1)  if the NOx monitor is a continuous emissions monitoring system (CEMS):

               (A)  subject to 40 Code of Federal Regulations (CFR) 75, use the missing data procedures specified in 40 CFR 75, Subpart D (Missing Data Substitution Procedures);

               (B)  subject to 40 CFR 75, Appendix E, use the missing data procedures specified in 40 CFR 75, Appendix E, Section 2.5 (Missing Data Procedures);

          (2)  use Appendix E monitoring in accordance with §117.143(d) of this title;

          (3)  if the NOx monitor is a predictive emissions monitoring system:

               (A)  use the methods specified in 40 CFR 75, Subpart D;

               (B)  use calculations in accordance with §117.143(f) of this title; or

          (4)  if the methods specified in paragraphs (1) - (3) of this subsection are not used, the owner or operator must use the maximum emission rate as measured by the testing conducted in accordance with §117.141(d) of this title (relating to Initial Demonstration of Compliance).

     (f)  The owner or operator of any unit subject to a system cap shall maintain daily records indicating the NOx emissions and fuel usage from each unit and summations of total NOx emissions and fuel usage for all units under the system cap on a daily basis.  Records shall also be retained in accordance with §117.149 of this title (relating to Notification, Recordkeeping, and Reporting Requirements).

     (g)  The owner or operator of any unit subject to a system cap shall submit annual reports for the monitoring systems in accordance with §117.149 of this title.  The owner or operator shall also report any exceedance of the system cap emission limit in the annual report and shall include an analysis of the cause for the exceedance with appropriate data to demonstrate the amount of emissions in excess of the applicable limit and the necessary corrective actions taken by the company to assure future compliance.

     (h)  The owner or operator of any unit subject to a system cap shall demonstrate initial compliance with the system cap in accordance with the schedule specified in §117.512 of this title (relating to Compliance Schedule for Utility Electric Generation in East and Central Texas).

     (i)  A unit which is permanently retired or decommissioned and rendered inoperable may be included in the source cap emission limit, provided that the permanent shutdown occurred on or after January 1, 1999.  The source cap emission limit is calculated in accordance with subsection (b) of this section.

     (j)  Emission reductions from shutdowns or curtailments which have been used for netting or offset purposes under the requirements of Chapter 116 of this title may not be included in the baseline for establishing the cap.

     (k)  For the purposes of determining compliance with the source cap emission limit, the contribution of each affected unit that is operating during a startup, shutdown, or upset period shall be calculated from the NOx emission rate measured by the NOx monitor, if operating properly.  If the NOx monitor is not operating properly, the substitute data procedures identified in subsection (e) of this section must be used.  If neither the NOx monitor nor the substitute data procedure are operating properly, the owner or operator must use the maximum daily rate measured during the initial demonstration of compliance, unless the owner or operator provides data demonstrating to the satisfaction of the executive director and EPA that actual emissions were less than maximum emissions during such periods.

************* end tx 117.138 adopted April 19, 2000 ****************b351**

§117.141.  Initial Demonstration of Compliance.
As adopted by TNRCC April 19, 2000, effective May 11, 2000

(Approved by EPA March 16, 2001 (66 FR 15195) effective April 16, 2001)

     (a)  The owner or operator of all units which are subject to the emission limitations of this division (relating to Utility Electric Generation in East and Central Texas) must be tested as follows.

          (1)  Test for nitrogen oxides (NOx), carbon monoxide (CO), and oxygen (O2) emissions.

          (2)  Units which inject urea or ammonia into the exhaust stream for NOx control shall be tested for ammonia emissions.

          (3)  Testing shall be performed in accordance with the schedule specified in §117.512 of this title (relating to Compliance Schedule for Utility Electric Generation in East and Central Texas).

     (b)  The tests required by subsection (a) of this section shall be used for determination of initial compliance with the emission limits of this division.  Test results shall be reported in the units of the applicable emission limits and averaging periods.  If compliance testing is based on 40 Code of Federal Regulations, Part 60, Appendix A reference methods, the report must contain the information specified in §117.211(g) of this title (relating to Initial Demonstration of Compliance).

     (c)  Continuous emissions monitoring systems (CEMS) or predictive emissions monitoring systems (PEMS) required by §117.143 of this title (relating to Continuous Demonstration of Compliance) shall be installed and operational before testing under subsection (a) of this section. Verification of operational status shall, at a minimum, include completion of the initial monitor certification and the manufacturer's written requirements or recommendations for installation, operation, and calibration of the device.

     (d)  Initial compliance with the emission specifications of this division for units operating with CEMS or PEMS in accordance with §117.143 of this title shall be demonstrated after monitor certification testing using the NOx CEMS or PEMS as follows.  To comply with the NOx emission limit in pound per million British thermal units (MM/Btu) on an annual average, NOx emissions from a unit are monitored for each unit operating day in a calendar year, and the annual average emission rate is used to determine compliance with the NOx emission limit.  The annual average emission rate is calculated as the average of all hourly emissions data recorded by the monitoring system during a calendar year.

************* end tx 117.141 adopted April 19, 2000 ****************b351**

§117.143.  Continuous Demonstration of Compliance.
As adopted by TNRCC April 19, 2000, effective May 11, 2000

(Approved by EPA March 16, 2001 (66 FR 15195) effective April 16, 2001)

     (a)  Nitrogen oxides (NOx) monitoring.  The owner or operator of each unit subject to the emission specifications of this division (relating to Utility Electric Generation in East and Central Texas) shall install, calibrate, maintain, and operate a continuous emissions monitoring system (CEMS), predictive emissions monitoring system (PEMS), or other system specified in this section to measure NOx on an individual basis.

     (b)  Carbon monoxide (CO) monitoring.  The owner or operator is not required to monitor CO exhaust emissions from each unit subject to the emission specifications of this division.

     (c)  CEMS requirements.

          (1)  Any CEMS required by this section shall be installed, calibrated, maintained, and operated in accordance with 40 Code of Federal Regulations (CFR), Part 75 or 40 CFR, Part 60, as applicable.

          (2)  One CEMS may be shared among units, provided:

               (A)  the exhaust stream of each unit is analyzed separately; and

               (B)  the CEMS meets the applicable certification requirements of paragraph (1) of this subsection for each exhaust stream.

     (d)  Acid rain peaking units.  The owner or operator of each peaking unit as defined in 40 CFR Part 72.2, may:

          (1)  monitor operating parameters for each unit in accordance with 40 CFR Part 75, Appendix E §1.1 or §1.2 and calculate NOx emission rates based on those procedures; or

          (2)  use CEMS or PEMS in accordance with this section to monitor NOx emission rates.

     (e)  Auxiliary boilers.  The owner or operator of each auxiliary boiler as defined in §117.10 of this title (relating to Definitions) shall:

          (1)  install, calibrate, maintain, and operate a CEMS in accordance with this section; or

          (2)  comply with the appropriate (considering boiler maximum rated capacity and annual heat input) industrial boiler monitoring requirements of §117.213 of this title (relating to Continuous Demonstration of Compliance).

     (f)  PEMS requirements.  The owner or operator of any PEMS used to meet a pollutant monitoring requirement of this section must comply with the following.  The required PEMS and fuel flow meters shall be used to demonstrate continuous compliance with the emission limitations of §117.135 of this title (relating to Emission Specifications).

          (1)  The PEMS must predict the pollutant emissions in the units of the applicable emission limitations of this division.

          (2)  Monitor diluent, either oxygen or carbon dioxide:

               (A)  using a CEMS:

                    (i)  in accordance with subsection (b) of this section; or

                    (ii)  with a similar alternative method approved by the executive director and EPA; or

               (B)  using a PEMS.

          (3)  Any PEMS for units subject to the requirements of 40 CFR 75 shall meet the requirements of 40 CFR 75 Subpart E, §§75.40 - 75.48.

          (4)  Any PEMS for units not subject to the requirements of 40 CFR 75 shall meet the requirements of either:

               (A)  40 CFR 75, Subpart E, §§75.40 - 75.48; or

               (B)  §117.213(f) of this title.

     (g)  Gas turbine monitoring.  The owner or operator of each stationary gas turbine subject to the emission specifications of §117.135 of this title, instead of monitoring emissions in accordance with the monitoring requirements of 40 CFR 75, may comply with the following monitoring requirements:

          (1)  for stationary gas turbines rated less than 30 megawatt (MW) or peaking gas turbines (as defined in §117.10 of this title) which use steam or water injection to comply with the emission specification of §117.135(2) of this title:

               (A)  install, calibrate, maintain and operate a CEMS or PEMS in compliance with this section; or

               (B)  install, calibrate, maintain, and operate a continuous monitoring system to monitor and record the average hourly fuel and steam or water consumption.  The system shall be accurate to within ± 5.0%.  The steam-to-fuel or water-to-fuel ratio monitoring data shall constitute the method for demonstrating continuous compliance with the emission specification of §117.135(2) of this title; and

          (2)  for gas turbines not subject to paragraph (1) of this subsection, install, calibrate, maintain and operate a CEMS or PEMS in compliance with this section.

     (h)  Totalizing fuel flow meters.  The owner or operator of units listed in this subsection shall install, calibrate, maintain, and operate totalizing fuel flow meters to individually and continuously measure the gas and liquid fuel usage.  A computer which collects, sums, and stores electronic data from continuous fuel flow meters is an acceptable totalizer.  The units are:

          (1)  any unit subject to the emission specifications of this division;

          (2)  any stationary gas turbine with an MW rating greater than or equal to 1.0 MW operated more than an average of 10% of the hours of the year, averaged over the three most recent calendar years, or more than 20% of the hours in a single calendar year; and

          (3)  any unit claimed exempt from the emission specifications of this division using the low annual capacity factor exemption of §117.133(1) of this title (relating to Exemptions).

     (i)  Run time meters.  The owner or operator of any stationary gas turbine using the exemption of §117.133(2) of this title shall record the operating time with an elapsed run time meter approved by the executive director.

     (j)  Loss of exemption.  The owner or operator of any unit claimed exempt from the emission specifications of this division using the low annual capacity factor exemptions of §117.133 of this title, shall notify the executive director within seven days if the applicable limit is exceeded.

          (1)  If the limit is exceeded, the exemption from the emission specifications of §117.135 of this title shall be permanently withdrawn.

          (2)  Within 90 days after loss of the exemption, the owner or operator shall submit a compliance plan detailing a plan to meet the applicable compliance limit as soon as possible, but no later than 24 months after exceeding the limit.  The plan shall include a schedule of increments of progress for the installation of the required control equipment.

          (3)  The schedule shall be subject to the review and approval of the executive director.

     (k)  Data used for compliance.  After the initial demonstration of compliance required by §117.141 of this title (relating to Initial Demonstration of Compliance) the methods required in this section shall be used to determine compliance with the emission specifications of this division. Compliance with the emission limitations may also be determined at the discretion of the executive director using any commission compliance method.

     (l)  Enforcement of NOx limits.  No unit subject to §117.135 of this title shall be operated at an emission rate higher than that allowed by the emission specifications of §117.135 of this title.

************* end tx 117.143 adopted April 19, 2000 ****************b351**

§117.145.  Final Control Plan Procedures.
As adopted by TNRCC April 19, 2000, effective May 11, 2000

(Approved by EPA March 16, 2001 (66 FR 15195) effective April 16, 2001)

     (a)  The owner or operator of units listed in §117.131 of this title (relating to Applicability) shall submit a final control report to show compliance with the requirements of §117.135 of this title (relating to Emission Specifications).  The report must include:

          (1)  the section under which nitrogen oxides (NOx) compliance is being established for the units within the electric generating system, either:

               (A)  §117.135 of this title; or

               (B)  §117.138 of this title (relating to System Cap);

          (2)  the methods of control of NOx emissions for each unit;

          (3)  the emissions measured by testing required in §117.141 of this title (relating to Initial Demonstration of Compliance);

          (4)  the submittal date, and whether sent to the Austin or the regional office (or both), of any compliance stack test report or relative accuracy test audit report required by §117.141 of this title which is not being submitted concurrently with the final compliance report; and

          (5)  the specific rule citation for any unit with a claimed exemption from the emission specification of §117.135 of this title.

     (b)  In addition to the requirements of subsection (a) of this section, the owner or operator of each source complying with §117.138 of this title shall submit:

          (1)  the calculations used to calculate the annual average system cap allowable emission rate;

          (2)  a list containing, for each unit in the cap:

               (A)  the average annual heat input Hi specified in §117.138(c) of this title;

               (B)  the method of monitoring emissions; and

               (C)  the method of providing substitute emissions data when the NOx monitoring system is not providing valid data; and

          (3)  an explanation of the basis of the value of Hi.

     (c)  The report must be submitted by the applicable date specified for final control plans in §117.512 of this title (relating to Compliance Schedule for Utility Electric Generation in East and Central Texas).  The plan must be updated with any emission compliance measurements submitted for units using a continuous emissions monitoring system or predictive emissions monitoring system and complying with the system cap annual average emission limit, according to the applicable schedule given in §117.512 of this title.

************* end tx 117.145 adopted April 19, 2000 ****************b351**

§117.147.  Revision of Final Control Plan.
As adopted by TNRCC April 19, 2000, effective May 11, 2000

(Approved by EPA March 16, 2001 (66 FR 15195) effective April 16, 2001)

     A revised final control plan may be submitted by the owner or operator, along with any required permit applications.  Such a plan shall adhere to the emission limits and the final compliance dates of this division (relating to Utility Electric Generation in East and Central Texas).  The revision of the final control plan shall be subject to the review and approval of the executive director.

************* end tx 117.147 adopted April 19, 2000 ****************b351**

§117.149.  Notification, Recordkeeping, and Reporting Requirements.
As adopted by TNRCC April 19, 2000, effective May 11, 2000

(Approved by EPA March 16, 2001 (66 FR 15195) effective April 16, 2001)

     (a)  Start-up and shutdown records.  For units subject to the start-up and/or shutdown exemptions allowed under §101.11 of this title (relating to Exemptions from Rules and Regulations), hourly records shall be made of start-up and/or shutdown events and maintained for a period of at least two years.  Records shall be available for inspection by the executive director, EPA, and any local air pollution control agency having jurisdiction upon request.  These records shall include, but are not limited to:  type of fuel burned; quantity of each type fuel burned; gross and net energy production in megawatt-hours (MW-hr); and the date, time, and duration of the event.

     (b)  Notification.  The owner or operator of a unit subject to the emission specifications of this division (relating to Utility Electric Generation in East and Central Texas) shall submit notification to the executive director as follows:

          (1)  verbal notification of the date of any initial demonstration of compliance testing conducted under §117.141 of this title (relating to Initial Demonstration of Compliance) at least 15 days prior to such date followed by written notification within 15 days after testing is completed; and

          (2)  verbal notification of the date of any continuous emissions monitoring systems (CEMS) or predictive emissions monitoring systems (PEMS) performance evaluation conducted under §117.143 of this title (relating to Continuous Demonstration of Compliance) at least 15 days prior to such date followed by written notification within 15 days after testing is completed.

     (c)  Reporting of test results.  The owner or operator of an affected unit shall furnish the executive director and any local air pollution control agency having jurisdiction a copy of any initial demonstration of compliance testing conducted under §117.141 of this title or any CEMS or PEMS performance evaluation conducted under §117.143 of this title:

          (1)  within 60 days after completion of such testing or evaluation; and

          (2)  not later than the appropriate compliance schedule specified in §117.512 of this title (relating to Compliance Schedule for Utility Electric Generation in East and Central Texas).

     (d)  Annual reports.  The owner or operator of a unit required to install a CEMS, PEMS, or steam-to-fuel or water-to-fuel ratio monitoring system under §117.143 of this title shall report in writing to the executive director on an annual basis any exceedance of the applicable emission limitations in this division and the monitoring system performance.  All reports shall be postmarked or received by January 31 following the end of each calendar year.  Written reports shall include the following information:

          (1)  the magnitude of excess emissions computed in accordance with 40 Code of Federal Regulations (CFR), Part 60, §60.13(h), any conversion factors used, the date and time of commencement and completion of each time period of excess emissions, and the unit operating time during the reporting period.  For stationary gas turbines using steam-to-fuel or water-to-fuel ratio monitoring to demonstrate compliance in accordance with §117.143 of this title, excess emissions are computed as each one-hour period during which the hourly steam-to-fuel or water-to-fuel ratio is less than the ratio determined to result in compliance during the initial demonstration of compliance test required by §117.141 of this title;

          (2)  specific identification of each period of excess emissions that occurs during start-ups, shutdowns, and malfunctions of the affected unit.  The nature and cause of any malfunction (if known) and the corrective action taken or preventative measures adopted;

          (3)  the date and time identifying each period during which the continuous monitoring system was inoperative, except for zero and span checks and the nature of the system repairs or adjustments;

          (4)  when no excess emissions have occurred or the continuous monitoring system has not been inoperative, repaired, or adjusted, such information shall be stated in the report; and

          (5)  if the total duration of excess emissions for the reporting period is less than 1.0% of the total unit operating time for the reporting period and the CEMS, PEMS, or steam-to-fuel or water-to-fuel ratio monitoring system downtime for the reporting period is less than 5.0% of the total unit operating time for the reporting period, only a summary report form (as outlined in the latest edition of the commission’s "Guidance for Preparation of Summary, Excess Emission, and Continuous Monitoring System Reports") shall be submitted, unless otherwise requested by the executive director. If the total duration of excess emissions for the reporting period is greater than or equal to 1.0% of the total operating time for the reporting period or the CEMS or steam-to-fuel or water-to-fuel ratio monitoring system downtime for the reporting period is greater than or equal to 5.0% of the total operating time for the reporting period, a summary report and an excess emission report shall both be submitted.

     (e)  Recordkeeping.  The owner or operator of a unit subject to the requirements of this division shall maintain records of the data specified in this subsection.  Records shall be kept for a period of at least five years and made available for inspection by the executive director, EPA, or local air pollution control agencies having jurisdiction upon request.  Operating records for each unit shall be recorded and maintained at a frequency equal to the applicable emission specification averaging period, or for units claimed exempt from the emission specifications based on low annual capacity factor, monthly.  Records shall include:

          (1)  emission rates in units of the applicable standards;

          (2)  gross energy production in MW-hr (not applicable to auxiliary boilers);

          (3)  quantity and type of fuel burned;

          (4)  the injection rate of reactant chemicals (if applicable); and

          (5)  emission monitoring data, pursuant to §117.143 of this title, including:

               (A)  the date, time, and duration of any malfunction in the operation of the monitoring system, except for zero and span checks, if applicable, and a description of system repairs and adjustments undertaken during each period;

               (B)  the results of initial certification testing, evaluations, calibrations, checks, adjustments, and maintenance of CEMS, PEMS, or operating parameter monitoring systems; and

               (C)  actual emissions or operating parameter measurements, as applicable;

          (6)  the results of performance testing, including initial demonstration of compliance testing conducted in accordance with §117.141 of this title; and

          (7)  records of hours of operation.

************* end tx 117.149 adopted April 19, 2000 ****************b35**
*********** end tnrcc reg 7 subchapter b division 2 *********eazs***b35**