API Publ 343:1998 pdf download

API Publ 343:1998 pdf download.FUGITIVE EMISSIONS FROM EQUIPMENT LEAKS II: CALCULATION PROCEDURES FOR PETROLEUMI NDUSTRY FACILITIES.
If emission correlauon equations are used. separate factors need to be used for components that are screened at background hydrocarbon concentrations (zero components) and also for components that are screened beyond the range of the screening instrument (pegged components). The recommended zero component emission rates and pegged component emission rates for refineries, petroleum marketing terminals, and the oil and gas industry are included in this section.
Note that the emissions estimate for an entire facility might include a combination of emission estimating methods.
Also discussed in this section are recommendations on fugitive emission estimation methods for petrochemical facilities and the recommended method to estimate equipment leak emissions of inorganic compounds.
3.1 AVERAGE EMISSION FACTOR MFHOD
Average emission factors do not require individual screening values for each conwonen Usually, the only necessary information is the number of components in each component (e.g., valves, connectors, etc.) and service type (gas, light hquid, heavy lic?rid) categories. The number of components in each category is multiplied by the appropriate average emission factor. The resulting mass emissions for each category can then be added together to determine the total hourly emissions from the facility. Annual emissions are obtained by innhiplying hourly emissions by the number of hours during
Average emission factors are typically used in facilities that do Dot have leak detection and repair programs. They can also be used to estimate emissions when new equipment is being added to a facility (i.e., a new process unit) and no screening values have yet been gathered from the new equpment. They are also used to estimate emissions from components that e not routinely monitored as pan of leak detection and repair programs (such as unsafe-to-moiutor,” or those in heavy liquid service).
Average refinery emission factors recommended by the U.S. EPA are shown in Table 3-1 (Epperson, 1995). The US. EPA 1980 refinery average emission ttors are based on data collected in the late 197k Note that this table has different emission factors for different component types and different service types. Light liquids are defined, for the average factors shown, as a liquid having a vapor pressure greater than 0.1 psia at 100°F or 689 Pa at 38°C. However, individual regulations may have different definitions for light liquids, heavy liquids, and gas. For instanee, the regulation NSPS Subpart 000 defines a ligh liquid as having a vapor pressure greaser than 0.3 k PA at 20°C for one or more constituents, or a 10% evaporation point at 150°C using ASThI Method.