Md. Code Regs. 26.09.02.11

Current through Register Vol. 51, No. 22, November 1, 2024

Section 26.09.02.11 - Record Keeping and Reporting

A. General Provisions. The CO₂ authorized account representative shall comply with all record-keeping and reporting requirements in this chapter and the applicable record-keeping and reporting requirements under 40 CFR § 75.73.

B. Quarterly Reports.

(1) The CO₂ authorized account representative shall submit quarterly reports as described in this section.

(2) The report shall contain the CO₂ mass emissions data for the CO₂ budget unit in an electronic format, unless otherwise required by the Department, for each calendar quarter beginning with:

(a) The calendar quarter covering January 1, 2009-March 31, 2009, for a unit that commences commercial operation before July 1, 2008; or

(b) For a unit commencing commercial operation on or after July 1, 2008, the calendar quarter corresponding to the earlier of the:

(i) Date of provisional certification; or

(ii) Applicable deadline for initial certification.

(3) If the quarter is the third or fourth quarter of 2008, reporting shall commence in the quarter covering January 1, 2009 through March 31, 2009.

(4) The CO₂ authorized account representative shall submit each quarterly report within 30 days following the end of the calendar quarter covered by the report and in accordance with 40 CFR Part 75, Subpart H, § 75.64 and 40 CFR Part 75, Subpart G except for the opacity, NO_X, and SO₂ provisions.

(5) Compliance Certification. The CO₂ authorized account representative shall submit a compliance certification in support of each quarterly report. The certification shall state that:

(a) The monitoring data submitted were recorded in accordance with the applicable requirements of this chapter and 40 CFR Part 75, including the quality assurance procedures and specifications;

(b) For a unit with add-on CO₂ emissions controls and for all hours where data are substituted in accordance with 40 CFR § 75.34(a)(1), the add-on emissions controls were operating within the range of parameters listed in the quality assurance and quality control program under 40 CFR Part 75, Appendix B, and the substitute values do not systematically underestimate CO₂ emissions; and

(c) The CO₂ concentration values substituted for missing data under 40 CFR Part 75, Subpart D, do not systematically underestimate CO₂ emissions.

C. Petitions for Alternative Requirements. The CO₂ authorized account representative of a CO₂ budget unit may submit a petition to the Department under 40 CFR § 75.66 requesting approval to apply an alternative to any requirement of this chapter.

D. CO₂ Budget Units that Burn Eligible Biomass.

(1) The CO₂ authorized account representative or alternate CO₂ authorized account representative of a CO₂ budget unit that burns eligible biomass as a compliance mechanism under this chapter shall report the following information for each calendar quarter:

(a) For each shipment of solid eligible biomass fuel fired at the CO₂ budget unit:

(i) Total eligible biomass fuel input, on an as-fired basis, in pounds; and

(ii) The moisture content, on an as-fired basis, as a fraction of weight;

(b) For each distinct type of gaseous eligible biomass fuel fired at the CO₂ budget unit:

(i) The density of the biogas, on an as-fired basis, in pounds per standard cubic foot; and

(ii) The moisture content of the biogas, as a fraction by total weight;

(c) For each distinct type of eligible biomass fuel fired at the CO₂ budget unit:

(i) The dry basis carbon content of the fuel type, as a fraction by dry weight;

(ii) The dry basis higher heating value, in MMBtu per dry pound;

(iii) The total dry basis eligible biomass fuel input, in pounds;

(iv) The total eligible biomass fuel heat input; and

(v) Chemical analysis, including heat value and carbon content;

(d) The total amount of CO₂ emitted from the CO₂ budget unit due to firing eligible biomass fuel, in tons, calculated as in §D(2)(b) of this regulation;

(e) The total heat input to the CO₂ budget unit due to firing eligible biomass fuel, in MMBtu, calculated in §D(4)(b) of this regulation; and

(f) Descriptions and documentation of monitoring technology and fuel sampling methodology employed, including sampling frequency;

(2) An owner or operator of a CO₂ budget unit shall calculate and submit on a quarterly basis the total dry weight for each distinct type of eligible biomass fired by the CO₂ budget unit during the reporting quarter as follows:

(a) For solid eligible biomass fuel, determined as follows:

Click here to view Image

where:

(i) F_j = Total eligible biomass dry basis fuel input (pounds) for fuel type j;

(ii) F_i = Eligible biomass as fired fuel input (pounds) for fired shipment i;

(iii) M_i = Moisture content (fraction) for fired shipment i;

(iv) i = fired fuel shipment;

(v) j = fuel type; and

(vi) m = number of shipments;

(b) For gaseous eligible biomass fuel, as determined as follows:

F_j = D_j x V_j x (1 - M_j)

where:

(i) F_j = Total eligible biomass dry basis fuel input (pounds) for fuel type j;

(ii) D_j = Density of biogas (pounds/scf) for fuel type j;

(iii) V_j = Total volume (scf) for fuel type j;

(iv) M_j = Moisture content (fraction) for fuel type j; and

(v) j = fuel type.

(3) The amount of CO₂ emissions that is produced from the firing of eligible biomass for any full calendar quarter, during which either no fuel other than eligible biomass is combusted or during which fuels other than eligible biomass are combusted, is determined as follows:

Click here to view Image

where:

(a) CO₂ tons = CO₂ emissions due to firing of eligible biomass for the reporting quarter;

(b) F_j = Total eligible biomass dry basis fuel input (pounds) for fuel type j, as calculated in §D(2)(a) of this regulation;

(c) C_j = Carbon fraction (dry basis) for fuel type j;

(d) O_j = Oxidation factor for eligible biomass fuel type j, derived for solid fuels based on the ash content of the eligible biomass fired and the carbon content of this ash; for gaseous eligible biomass fuels, a default oxidation factor of 0.995 may be used;

Click here to view Image

The number of tons of carbon dioxide that are created when 1 ton of carbon is combusted;

(f) 0.0005 = The number of short tons which is equal to 1 pound;

(g) j = Fuel type; and

(h) n = number of distinct fuel types.

(4) Heat input due to firing of eligible biomass for each quarter shall be determined as follows:

(a) For each distinct fuel type:

H_j = F_j x HHV_j

where:

(i) H_j = Heat input (MMBtu) for fuel type j;

(ii) F_j = Total eligible biomass dry basis fuel input (pounds) for fuel type j;

(iii) HHV_j = Higher heating value (MMBtu/pound), dry basis, for fuel type j, as determined through chemical analysis;

(iv) j = Fuel type;

(b) For all fuel types:

Click here to view Image

where:

(i) H_j = Heat input (MMBtu) for fuel type j;

(ii) j = fuel type; and

(iii) n = number of distinct fuel types.

(5) Fuel sampling methods and fuel sampling technology shall be consistent with the New York State Renewable Portfolio Standard Biomass Guidebook, May 2006.

E. Additional Requirements to Provide Output Data.

(1) Report of Megawatt-Hours of Electrical Output. A CO₂ budget unit shall submit to the Department the megawatt-hour value and a statement certifying that the megawatt-hour of electrical output reported reflects the total actual electrical output for all CO₂ budget units at the facility used by the independent system operator (ISO) to determine settlement resources of energy market participants.

(2) Report of Gross Hourly Megawatts. A CO₂ budget unit shall report gross hourly megawatts to the Department in the same electronic data report (EDR) for gross output as submitted to the EPA Administrator, for the operating time in the hour, added for all hours in a year.

(3) Report of Net Electrical Output. A CO₂ budget unit shall submit the net electrical output to the Department in accordance with this regulation. A CO₂ budget source whose electrical output is not used in the independent system operator (ISO) energy market settlement determinations shall propose a method for quantification of net electrical output.

(4) Report of Net Steam Output.

(a) CO₂ budget sources selling steam shall use billing meters to determine net steam output or an alternative method to measure net steam output approved by the Department.

(b) If data for steam output is not available, the CO₂ budget source may report heat input, substituting useful steam output for steam output.

F. Output Monitoring Plan.

(1) The owner or operator of each CO₂ budget unit shall report net output described in this section.

(2) Each CO₂ budget source shall submit an output monitoring plan with a description and diagram that include the following:

(a) If the CO₂ budget unit monitors net electric output, the diagram shall contain all CO₂ budget units and all generators served by each CO₂ budget unit and the relationship between CO₂ budget units and generators;

(b) If a generator served by a CO₂ budget unit is also served by a nonaffected unit, the nonaffected unit and its relationship to each generator shall be indicated on the diagram;

(c) The diagram shall indicate where the net electric output is measured and include all electrical inputs and outputs to and from the plant;

(d) If net electric output is determined using a billing meter, the diagram shall show each billing meter used to determine net sales of electricity and show that all electricity measured at the point of sale is generated by the CO₂ budget units;

(e) If the CO₂ budget unit monitors net thermal output, the diagram shall indicate all steam or hot water coming into the net steam system, including steam from CO₂ budget units and nonaffected units, and all exit points of steam or hot water from the net steam system;

(f) Each input and output stream shall have an estimated temperature, pressure and phase indicator, and an enthalpy in Btu per pound;

(g) The diagram of the net steam system shall identify all useful loads, house loads, parasitic loads, any other steam loads, and all boiler feedwater returns;

(h) The diagram shall represent all energy losses in the system as either usable or unusable losses;

(i) The diagram shall indicate all flow meters, temperature or pressure sensors, or other equipment used to calculate gross thermal output; and

(j) If a sales agreement is used to determine net thermal output, the diagram shall show the monitoring equipment used to determine the sales of steam.

(3) Description of Output Monitoring System.

(a) The description of the output monitoring system shall include:

(i) A written description of the output system and the equations used to calculate output, and, for net thermal output systems, descriptions and justifications of each useful load;

(ii) A detailed description of all quality assurance and quality control activities that will be performed to maintain the output system; and

(iii) Documentation supporting any output value to be used as a missing data value if there are periods of invalid output data.

(b) The missing data output value shall be either zero or an output value that is likely to be lower than a measured value and approved as part of the required monitoring plan.

G. Initial Certification Statement and Billing Meters.

(1) A certification statement shall be submitted by the CO₂ authorized account representative stating that either:

(a) The output monitoring system consists entirely of billing meters; or

(b) The output monitoring system meets one of the accuracy requirements for nonbilling meters.

(2) The billing meter shall record the electric or thermal output. Any electric or thermal output values reported shall be the same as the values used in billing for the output.

(3) For nonbilling meters, either the output monitoring system shall meet an accuracy of within 10 percent of the reference value, or each component monitor for the output system shall meet an accuracy of within 3 percent of the full scale value, whichever is less stringent.

(4) The system approach to accuracy shall include:

(a) A determination of how the system accuracy of 10 percent is achieved using the individual components in the system; and

(b) Data loggers and any wattmeters used to calculate the final net electric output data or any flowmeters for steam or condensate, temperature measurement devices, absolute pressure measurement devices, and differential pressure devices used for measuring thermal energy.

(5) If, upon testing a piece of output measurement equipment, it is determined that the output readings are not accurate to within 3 percent of the full scale value, then the equipment shall be repaired or replaced to meet that requirement.

(6) Data is invalid until the output measurement equipment passes an accuracy test or is replaced with another piece of equipment that passes the accuracy test.

H. Ongoing Quality Assurance and Quality Control.

(1) Ongoing quality assurance and quality control activities shall be performed in order to maintain the output system.

(2) Billing Meters. If billing meters are used to determine output, quality assurance and quality control activities are not required beyond what are already performed.

(3) Nonbilling Meters.

(a) Certain types of equipment such as potential transformers, current transformers, nozzle and venturi type meters, and the primary element of an orifice plate only require an initial certification of calibration and do not require periodic recalibration unless the equipment is physically changed.

(b) Pressure and temperature transmitters accompanying an orifice plate will require periodic retesting.

(c) For other types of equipment, the meter accuracy shall be recalibrated or verified at least once every 2 years, unless a consensus standard allows for less frequent calibrations or accuracy tests.

(d) For nonbilling meters, either the output monitoring system shall meet an accuracy of within 10 percent of the reference value, or each component monitor for the output system shall meet an accuracy of within 3 percent of the full scale value, whichever is less stringent.

(e) If, upon testing a piece of output measurement equipment, it is determined that the output readings are not accurate to within 3 percent of the full scale value, then the equipment shall be repaired or replaced to meet that requirement.

(4) Out-of-Control Periods.

(a) If, upon testing a piece of output measurement equipment, it is determined that the output readings are not accurate to the certification value, data is invalid until the output measurement equipment passes an accuracy test or is replaced with another piece of equipment that passes the accuracy test.

(b) All invalid data shall be replaced by either zero or an output value that is likely to be lower than a measured value and that is approved as part of the required monitoring plan.

I. Annual Reports. The CO₂ authorized account representative shall submit annual output reports, as follows:

(1) Data shall be sent both electronically and in hardcopy by March 1 for the immediately preceding calendar year; and

(2) The annual report shall include unit level megawatt hours, all useful steam output, and a certification statement from the CO₂ authorized account representative stating the following, "I am authorized to make this submission on behalf of the owners and operators of the CO₂ budget sources or CO₂ budget units for which the submission is made. I certify under penalty of law that I have personally examined, and am familiar with, the statements and information submitted in this document and all its attachments. Based on my inquiry of those individuals with primary responsibility for obtaining the information, I certify that the statements and information are to the best of my knowledge and belief true, accurate, and complete. I am aware that there are significant penalties for submitting false statements and information or omitting required statements and information, including the possibility of fine or imprisonment".

Md. Code Regs. 26.09.02.11

Regulation .11 amended effective 45:26 Md. R. 1249, eff. 12/31/2018