§ 75.55 - General recordkeeping provisions for specific situations.

Link to an amendment published at 67 FR 40440, June 12, 2002.

Before April 1, 2000, the owner or operator shall meet the requirements of either this section or § 75.58. On and after April 1, 2000, the owner or operator shall meet the requirements of § 75.58.

(a) Specific SO2emission record provisions for units with qualifying Phase I technology. In addition to the SO2 emissions information required in § 75.54(c), from January 1, 1997, through December 31, 1999, the owner or operator shall record the applicable information in this paragraph for each affected unit on which SO2 emission controls have been installed and operated for the purpose of meeting qualifying Phase I technology requirements pursuant to § 72.42 of this chapter and § 75.15.

(1) For units with post-combustion emission controls:

(i) Component/system identification codes for each inlet and outlet SO2-diluent continuous emission monitoring system;

(ii) Date and hour;

(iii) Hourly average inlet SO2 emission rate (lb/mmBtu, rounded to nearest hundredth);

(iv) Hourly average outlet SO2 emission rate (lb/mmBtu, rounded to nearest hundredth);

(v) Percent data availability for both inlet and outlet SO2-diluent continuous emission monitoring systems (recorded to the nearest tenth of a percent), calculated pursuant to equation 8 of § 75.32 (for the first 8,760 unit operating hours following initial certification) and equation 9 of § 75.32, thereafter; and

(vi) Identification code for emissions formula used to derive hourly average inlet and outlet SO2 mass emissions rates for each affected unit or group of units using a common stack.

(2) For units with combustion and/or pre-combustion emission controls:

(i) Component/system identification codes for each outlet SO2-diluent continuous emission monitoring system;

(ii) Date and hour;

(iii) Hourly average outlet SO2 emission rate (lb/mmBtu, rounded to nearest hundredth);

(iv) For units with combustion controls, average daily inlet SO2 emission rate (lb/mmBtu, rounded to nearest hundredth), determined by coal sampling and analysis procedures in § 75.15; and

(v) For units with pre-combustion controls (i.e., fuel pretreatment), fuel analysis demonstrating the weight, sulfur content, and gross calorific value of the product and raw fuel lots.

(b) Specific parametric data record provisions for calculating substitute emissions data for units with add-on emission controls. In accordance with § 75.34, the owner or operator of an affected unit with add-on emission controls shall either record the applicable information in paragraph (b)(3) of this section for each hour of missing SO2 concentration data or NOX emission rate (in addition to other information), or shall record the information in paragraph (b)(1) of this section for SO2 or paragraph (b)(2) of this section for NOX through an automated data acquisition and handling system, as appropriate to the type of add-on emission controls:

(1) For units with add-on SO2 emission controls petitioning to use or using the optional parametric monitoring procedures in appendix C of this part, for each hour of missing SO2 concentration or volumetric flow data:

(i) The information required in § 75.54(c) for SO2 concentration and volumetric flow if either one of these monitors is still operating:

(ii) Date and hour;

(iii) Number of operating scrubber modules;

(iv) Total feedrate of slurry to each operating scrubber module (gal/min);

(v) Pressure differential across each operating scrubber module (inches of water column);

(vi) For a unit with a wet flue gas desulfurization system, an inline measure of absorber pH for each operating scrubber module;

(vii) For a unit with a dry flue gas desulfurization system, the inlet and outlet temperatures across each operating scrubber module;

(viii) For a unit with a wet flue gas desulfurization system, the percent solids in slurry for each scrubber module.

(ix) For a unit with a dry flue gas desulfurization system, the slurry feed rate (gal/min) to the atomizer nozzle;

(x) For a unit with SO2 add-on emission controls other than wet or dry limestone, corresponding parameters approved by the Administrator;

(xi) Method of determination of SO2 concentration and volumetric flow, using Codes 1-15 in Table 4 of § 75.54; and

(xii) Inlet and outlet SO2 concentration values recorded by an SO2 continuous emission monitoring system and the removal efficiency of the add-on emission controls.

(2) For units with add-on NOX emission controls petitioning to use or using the optional parametric monitoring procedures in appendix C of this part, for each hour of missing NOX emission rate data:

(i) Date and hour;

(ii) Inlet air flow rate (acfh, rounded to the nearest thousand);

(iii) Excess O2 concentration of flue gas at stack outlet (percent, rounded to nearest tenth of a percent);

(iv) Carbon monoxide concentration of flue gas at stack outlet (ppm, rounded to the nearest tenth);

(v) Temperature of flue gas at furnace exit or economizer outlet duct ( °F); and

(vi) Other parameters specific to NOX emission controls (e.g., average hourly reagent feedrate);

(vii) Method of determination of NOX emission rate using Codes 1-15 in Table 4 of § 75.54; and

(viii) Inlet and outlet NOX emission rate values recorded by a NOX continuous emission monitoring system and the removal efficiency of the add-on emission controls.

(3) For units with add-on SO2 or NOX emission controls following the provisions of § 75.34 (a)(1) or (a)(2), the owner or operator shall, for each hour of missing SO2 or NOX emission data, record:

(i) Parametric data which demonstrate the proper operation of the add-on emission controls, as described in the quality assurance/quality control program for the unit. The parametric data shall be maintained on site, and shall be submitted upon request to the Administrator, an EPA Regional office, State, or local agency;

(ii) A flag indicating either that the add-on emission controls are operating properly, as evidenced by all parameters being within the ranges specified in the quality assurance/quality control program, or that the add-on emission controls are not operating properly;

(iii) For units petitioning under § 75.66 for substituting a representative SO2 concentration during missing data periods, any available inlet and outlet SO2 concentration values recorded by an SO2 continuous emission monitoring system; and

(iv) For units petitioning under § 75.66 for substituting a representative NOX emission rate during missing data periods, any available inlet and outlet NOX emission rate values recorded by a NOX continuous emission monitoring system.

(c) Specific SO2emission record provisions for gas-fired or oil-fired units using optional protocol in appendix D of this part. In lieu of recording the information in § 75.54(c) of this section, the owner or operator shall record the applicable information in this paragraph for each affected gas-fired or oil-fired unit for which the owner or operator is using the optional protocol in appendix D of this part for estimating SO2 mass emissions.

(1) For each hour when the unit is combusting oil:

(i) Date and hour;

(ii) Hourly average flow rate of oil with the units in which oil flow is recorded, (gal/hr, lb/hr, m3/hr, or bbl/hr, rounded to the nearest tenth)(flag value if derived from missing data procedures);

(iii) Sulfur content of oil sample used to determine SO2 mass emissions, rounded to nearest hundredth for diesel fuel or to the nearest tenth of a percent for other fuel oil (flag value if derived from missing data procedures);

(iv) Method of oil sampling (flow proportional, continuous drip, as delivered or manual);

(v) Mass of oil combusted each hour (lb/hr, rounded to the nearest tenth);

(vi) SO2 mass emissions from oil (lb/hr, rounded to the nearest tenth);

(vii) For units using volumetric oil flowmeters, density of oil (flag value if derived from missing data procedures);

(viii) Gross calorific value (heat content) of oil, used to determine heat input (Btu/mass unit) (flag value if derived from missing data procedures);

(ix) Hourly heat input rate from oil according to procedures in appendix F of this part (mmBtu/hr, to the nearest tenth); and

(x) Fuel usage time for combustion of oil during the hour, rounded up to the nearest 15 min.

(2) For gas-fired units or oil-fired units using the optional protocol in appendix D of this part of daily manual oil sampling, when the unit is combusting oil, the highest sulfur content recorded from the most recent 30 daily oil samples rounded to nearest tenth of a percent.

(3) For each hour when the unit is combusting gaseous fuel,

(i) Date and hour;

(ii) Hourly heat input rate from gaseous fuel according to procedures in appendix F to this part (mmBtu/hr, rounded to the nearest tenth);

(iii) Sulfur content or SO2 emission rate, in one of the following formats, in accordance with the appropriate procedure from appendix D of this part:

(A) Sulfur content of gas sample, (rounded to the nearest 0.1 grains/100 scf) (flag value if derived from missing data procedures); or

(B) SO2 emission rate of 0.0006 lb/mmBtu for pipeline natural gas;

(iv) Hourly flow rate of gaseous fuel, in 100 scfh (flag value if derived from missing data procedures);

(v) Gross calorific value (heat content) of gaseous fuel, used to determine heat input (Btu/scf) (flag value if derived from missing data procedures);

(vi) Heat input rate from gaseous fuel (mmBtu/hr, rounded to the nearest tenth);

(vii) SO2 mass emissions due to the combustion of gaseous fuels, lb/hr; and

(viii) Fuel usage time for combustion of gaseous fuel during the hour, rounded up to the nearest 15 min.

(4) For each oil sample or sample of diesel fuel:

(i) Date of sampling;

(ii) Sulfur content (percent, rounded to the nearest hundredth for diesel fuel and to the nearest tenth for other fuel oil) (flag value if derived from missing data procedures);

(iii) Gross calorific value or heat content (Btu/lb) (flag value if derived from missing data procedures); and

(iv) Density or specific gravity, if required to convert volume to mass (flag value if derived from missing data procedures).

(5) For each daily sample of gaseous fuel:

(i) Date of sampling;

(ii) Sulfur content (grains/100 scf, rounded to the nearest tenth) (flag value if derived from missing data procedures);

(6) For each monthly sample of gaseous fuel:

(i) Date of sampling;

(ii) Gross calorific value or heat content (Btu/scf) (flag value if derived from missing data procedures).

(d) Specific NOXemission record provisions for gas-fired peaking units or oil-fired peaking units using optional protocol in appendix E of this part. In lieu of recording the information in paragraph § 75.54(d), the owner or operator shall record the applicable information in this paragraph for each affected gas-fired peaking unit or oil-fired peaking unit for which the owner or operator is using the optional protocol in appendix E of this part for estimating NOX emission rate.

(1) For each hour when the unit is combusting oil,

(i) Date and hour;

(ii) Hourly average fuel flow rate of oil with the units in which oil flow is recorded (gal/hour, lb/hr or bbl/hour) (flag value if derived from missing data procedures);

(iii) Gross calorific value (heat content) of oil, used to determine heat input (Btu/lb) (flag value if derived from missing data procedures);

(iv) Hourly average NOX emission rate from combustion of oil (lb/mmBtu);

(v) Heat input rate of oil (mmBtu/hr, rounded to the nearest tenth); and

(vi) Fuel usage time for combustion of oil during the hour, rounded to the nearest 15 min.

(2) For each hour when the unit is combusting gaseous fuel,

(i) Date and hour;

(ii) Hourly average fuel flow rate of gaseous fuel (100 scfh) (flag value if derived from missing data procedures);

(iii) Gross calorific value (heat content) of gaseous fuel, used to determine heat input (Btu/scf) (flag value if derived from missing data procedures);

(iv) Hourly average NOX emission rate from combustion of gaseous fuel (lb/mmBtu, rounded to nearest hundredth);

(v) Heat input rate from gaseous fuel (mmBtu/hr, rounded to the nearest tenth); and

(vi) Fuel usage time for combustion of gaseous fuel during the hour, rounded to the nearest 15 min.

(3) For each hour when the unit combusts any fuel:

(i) Date and hour;

(ii) Total heat input from all fuels (mmBtu, rounded to the nearest tenth);

(iii) Hourly average NOX emission rate for the unit for all fuels;

(iv) For stationary gas turbines and diesel or dual-fuel reciprocating engines, hourly averages of operating parameters under section 2.3 of appendix E (flag if value is outside of manufacturer's recommended range);

(v) For boilers, hourly average boiler O2 reading (percent, rounded to the nearest tenth) (flag if value exceeds by more than 2 percentage points the O2 level recorded at the same heat input during the previous NOX emission rate test).

(4) For each fuel sample:

(i) Date of sampling;

(ii) Gross calorific value (heat content) (Btu/lb for oil, Btu/scf for gaseous fuel); and

(iii) Density or specific gravity, if required to convert volume to mass.

(e) Specific SO2emission record provisions during the combustion of gaseous fuel. (1) If SO2 emissions are determined in accordance with the provisions in § 75.11(e)(2) during hours in which only gaseous fuel is combusted in a unit with an SO2 CEMS, the owner or operator shall record the information in paragraph (c)(3) of this section in lieu of the information in §§ 75.54(c)(1) and (c)(3) or §§ 75.57(c)(1) and (c)(4), for those hours.

(2) The provisions of this paragraph apply to a unit which, in accordance with the provisions of § 75.11(e)(3), uses an SO2 CEMS to determine SO2 emissions during hours in which only gaseous fuel is combusted in the unit. If the unit sometimes burns only gaseous fuel that is very low sulfur fuel (as defined in § 72.2 of this chapter) as a primary and/or backup fuel and at other times combusts higher-sulfur fuels, such as coal or oil, as primary and/or backup fuel(s), then the owner or operator shall keep records on-site, suitable for inspection, of the type(s) of fuel(s) burned during each period of missing SO2 data and the number of hours that each type of fuel was combusted in the unit during each missing data period. This recordkeeping requirement does not apply to an affected unit that burns very low sulfur fuel exclusively, nor does it apply to a unit that burns such gaseous fuel(s) only during unit startup.

Effective Date Note:

At 67 FR 40440, June 12, 2002, § 75.55 was removed and reserved, effective July 12, 2002.