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3.5.2.1 Diluent Injection The first technique used to reduce NOx emissions was injection of water or steam into the high temperature flame zone. Water and steam are strong diluents and can quench hot spots in the flame reducing NOx. However, because positioning of the injection is not precise some NOx is still created. Depending on uncontrolled NOx levels, water or steam injection reduces NOx by 60 percent or more. Water or steam injection enables gas turbines to operate with NOx levels as low as 25 ppm (@ 15 percent O2) on natural gas. NOx is reduced only to 42 to 75 ppm when firing with liquid distillate fuel. Both water and steam increase the mass flow through the turbine and create a small amount of additional power. Use of exhaust heat to raise the steam temperature also increases overall efficiency slightly. The water used needs to be demineralized thoroughly in order to avoid forming deposits and corrosion in the turbine expansion section. This adds cost and complexity to the operation of the turbine. Diluent injection increases CO emissions appreciably as it lowers the temperature in the burnout zone, as well as in the NOx formation zone. 3.5.2.2 Lean Premixed Combustion Lean premixed combustion (DLN/DLE54) pre-mixes the gaseous fuel and compressed air so that there are no local zones of high temperatures, or "hot spots," where high levels of NOx would form. Lean premixed combustion requires specially designed mixing chambers and mixture inlet zones to avoid flashback of the flame. Optimized application of DLN combustion requires an integrated approach for combustor and turbine design. The DLN combustor becomes an intrinsic part of the turbine design, and specific combustor designs must be developed for each turbine application. While NOx levels as low as 9 ppm have been achieved, most manufacturers typically offer a range of 15-25 ppm DLN/DLE combustion systems when operating on natural gas. 3.5.2.3 Selective Catalytic Reduction (SCR) The primary post-combustion NOx control method in use today is SCR. Ammonia is injected into the flue gas and reacts with NOx in the presence of a catalyst to produce N2 and H2O. The SCR system is located in the exhaust path, typically within the HRSG where the temperature of the exhaust gas matches the operating temperature of the catalyst. The operating temperature of conventional SCR systems ranges from 400 to 800°F. The cost of conventional SCR has dropped significantly over time—catalyst innovations have been a principal driver, resulting in a 20 percent reduction in catalyst volume and cost with no change in performance. SCR reduces between 80 to 90 percent of the NOx in the gas turbine exhaust, depending on the degree to which the chemical conditions in the exhaust are uniform. When used in series with water/steam injection or DLN combustion, SCR can result in low single digit NOx levels (1.5 to 5 ppm). SCR requires on-site storage of ammonia, a hazardous chemical. In addition, ammonia can “slip” through the process unreacted, contributing to environmental and health concerns.55 54 Dry low NOx/Dry low emissions 55 The SCR reaction, with stoichiometric ammonia (for NOx reduction) or other reagent should eliminate all NOx. However, because of imperfect mixing in the combustor the NOx is not uniformly distributed across the turbine exhaust. Additionally, the ammonia, or other reagent, also is not injected in a precisely uniform manner. These two non-uniformities in chemical composition cause either excess ammonia to be used, and to consequently "slip" out of the exhaust, or for incomplete reaction of the NOx in the turbine exhaust. Catalog of CHP Technologies 3–18 Combustion TubinesPDF Image | EPA CHP Technologies Combustion Turbines
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