Facility Name: Ingersoll-Rand Energy Systems Contact: Randy Finstad Engineer: G. Milbury Facility ID No.: 3301500024 FY05-0146 application rec'd 8/4/05 603-430-7091 Date: 11/22/2005 Facility Address: 30 New Hampshire Avenue, Portsmouth, NH 03801-2811
EMISSION CALCULATIONS FOR NINE 250 Kw AND SIX 70 Kw MICROTURBINE TEST STATIONS USING NATURAL GAS OR PROPANE
Project Description: New application for nine (9) 250 kW and six (6) 70 kW microturbine test stations. The microturbines use primarily natural gas but are capable of firing on propane. Ingersoll-Rand is a manufacturer of microturbines; however, microturbines are not manufactured at this location. This facility only conducts performance testing on the microturbines. For maximum operational flexibility, potential emissions are calculated assuming that the higher emitting device is operating in each of the fifteen test stations. Based on this assumption, potential facility-wide NOx, SO2, and PM emissions are calculated based on the 250 kW units located at all 15 test stations, while CO and VOC emissions are calculated based on the 70 kW units located at all 15 test stations.
Emission Factors are in pounds per million cubic feet (lb/MMCF) of gas for PM and SO2. All other factors in pounds per hour.
SO2 PM10 VOC
Fuel/Sulfur Emission Factor Source NOx (lb/hr)* CO (lb/hr)* (lb/MMCF) (lb/MMCF) (lb/hr)* For 250 kW Microturbines: For PM and SO2 - AP-42, Chapter 3.1, (April 2000) Stationary Gas Natural Gas or Propane Turbines. For NOx, CO, and VOC, source specific stack test data. 0.0165 0.011 0.6 6.732 0.0033 For 70 kW Microturbines: For PM and SO2 - AP-42, Chapter 3.1, (April 2000) Stationary Gas Natural Gas or Propane Turbines. For NOx, CO, and VOC, source specific stack test data. 0.011 0.022 0.6 6.732 0.0044
Note: No emissions factors are available for propane gas. However, emissions are expected to be approximately the same as when firing natural gas.
* Hourly emission factors for NOx, CO, and VOC based on maximum measured emission rates during stack test @100% load, plus 10% adjustment factor to account for variablility in test results (per DES policy).
Device Description fuel flow Input Rating rate per ** Note - Each test station has a separate Device ID Installation Manufacturer Model # Serial # Per Device fuel type device exhaust stack Date (MMBtu/hr) (MMCF/hr) height (ft) dia (ft) flow (acfm) temp (F) 300 (w/ cogen)/ Nine 250 kW Microturbine Test natural gas or 480 w/o Stations Nov-02 Ingersoll-Rand 250LM N/A 3.3 propane 0.003235 35 1.75 3,200 cogen 300 (w/ cogen)/ Six 70 kW Microturbine Test natural gas or 480 w/o Stations Nov-02 Ingersoll-Rand 70LM N/A 0.9 propane 0.000882 31 1.167 1,300 cogen
Potential (and Permitted) Emissions using Natural Gas or Propane (Emissions assumed to be approximately equal for either fuel)
Pollutant NOx CO SO2 PM10 VOC Emission Factor (lb/MMCF or lb/hr as noted) 0.6 6.732 lbs/hr tpy lbs/hr tpy lbs/hr tpy lbs/hr tpy lbs/hr tpy Fifteen Microturbine Test Stations For each turbine 0.017 0.07 0.022 0.10 0.002 0.01 0.022 0.10 0.004 0.02 Total for all test stations combined 0.248 1.08 0.33 1.45 0.03 0.13 0.33 1.43 0.07 0.29
425.12 MMCF/yr natural gas or prop The facility does not have the potential to emit NOx or other criteria pollutants greater than 100 tons per year and thus is considered a true minor source. maximum sulfur content of 15 gr/100 CF
above gas usage assumes all 15 test stations operating 250 kW units 8,760 hours per year. Fuel Heat Content No. 6 fuel oil 150,000 Btu/gal No. 4 fuel oil 145,000 Btu/gal No. 2 fuel oil 140,000 Btu/gal Diesel fuel 137,000 Btu/gal Kerosene 135,000 Btu/gal Propane 94,000 Btu/gal Natural Gas 1,020 Btu/cf pane