This report provides a summary and analysis of selected provisions of S. 1733 , the Clean Energy Jobs and American Power Act. The topics covered include electric power and incentives for the development of natural gas technologies. The report also compares those provisions with counterparts, if any, in H.R. 2454 , the American Clean Energy and Security Act. Other aspects of S. 1733 and H.R. 2454 are covered in additional CRS reports. These reports are available in the climate change section of the CRS website, located at http://crs.gov/Pages/subissue.aspx?cliid=2645&parentid=2522 . The remainder of this report is divided into the following sections: Electric Power and Natural Gas Technologies. Electric Power Transmission and Related Technologies Subtitle H of Division A has two sections dealing with the use of low carbon emitting energy technologies. Section 181, Clean Energy and Accelerated Emission Reduction Program , directs the EPA administrator to "establish a program to promote dispatchable power generation projects that can accelerate the reduction of power sector carbon dioxide and other greenhouse gas emissions" (emphasis added). The term "dispatchable" is not defined in the bill, but would normally refer to power generating units that can be run at-will by system operators. In this sense a natural gas, nuclear, or coal unit is dispatchable while a wind or solar plant is not, because wind and solar generation is dependent on weather and diurnal conditions. The EPA administrator is directed to establish rules within 90 days of enactment for providing incentives to dispatchable power projects that generate 300,000 gigawatt-hours (Gwh) of electricity annually. To put this generation target in context, a reasonably large power plant with a capacity of 500 megawatts (i.e., 0.5 gigawatts) that operates the equivalent of 85% of the time would generate 3,723 Gwh annually. Therefore it would take about 81 of these 500 Mw plants to meet the goal of generating 300,000 Gwh annually under this program. To qualify for incentives, an eligible project must produce emissions of greenhouse gases (GHG) that are below the 2007 average emissions per megawatt-hour (Mwh) by the United States electric power sector, according to the following schedule ( Table 1 ): The bill speaks to reductions in the emissions of all GHG released by power plants, but information is readily available only for power plant carbon dioxide emissions (CO 2 is, in any event, the predominant GHG in the electric power sector). Table 2 , below, shows average CO 2 emission per Mwh for the electric power sector as a whole in 2007, the 2007 values for several specific combustible fuel sources, and estimated emissions for new natural gas plants. These estimates, which include no carbon controls, show that only new high efficiency natural gas plants can meet the reduction targets of 25% for 2010 to 2020 and 40% for 2021 to 2025. It does not appear that any combustible fuel source can meet the 65% target which begins in 2026 without carbon controls. Nuclear power is a dispatchable option which could meet these targets since carbon emissions are essentially zero. Geothermal power has very small emissions per Mwh ( Table 2 ) and is dispatchable, but with current technology plants are limited to small installations in the western United States. Another alternative could be to link wind or solar power with electricity storage, creating a combined system which could be dispatched as needed However, current electricity storage technologies are limited by cost, technical, and environmental factors. In allocating incentives the administrator is to give priority to projects with one or more of the following characteristics: Power generation and energy storage projects intended to integrate variable renewable electricity sources, such as solar and wind power, into the grid. Power generation projects with carbon capture and sequestration that do not qualify for other aid under S. 1733 . Projects that achieve the greatest reduction in GHG emissions per dollar of incentive payment. Several features of Section 181 are unspecified or unclear. These include: The total dollar amount and form of the incentives. By what point in time projects must enter service to qualify for incentives. Whether the emission reduction target varies for a project over time. For example, assume a project enters service in 2010 and must therefore meet the 25 percent reduction in GHG emission goal ( Table 1 ). If the project is still operating in 2021 to 2025, does it have to further reduce emissions to meet the 40% reduction target that begins in that period in order to continue to receive incentives, or does the higher target only apply to new units that enter service during that period? The bill states that "Not later than 3 years after the date of enactment of this Act, the Administrator shall provide incentives for eligible projects that generate 300,000 gigawatt-hours of electricity per year." It is not clear from this language if the Administrator must make all awards within three years of enactment, or must merely begin making awards by that deadline. Section 182 of Subtitle H, Advanced Natural Gas Technologies , would establish two programs for accelerating the deployment of advanced natural gas technologies. Under one program, for "Natural Gas Electricity Generation Grants," the EPA Administrator "may provide" (but apparently is not required to provide) research and development grants "to support the deployment of low greenhouse-gas-emitting end-use technologies, including carbon capture and sequestration technologies, for natural gas electricity generation." Under the second program, for "Natural Gas Residential and Commercial Technology Grants," the Administrator is directed to establish a grant program for research, development, demonstration, and deployment of low GHG emitting end-use technologies for the commercial and residential sectors. Grants can be made to private or municipal utilities, research and development establishments, and other types of businesses. Although these programs are under the direction of the EPA, the Secretary of Energy is the official directed to report to the Congress every 180 days on the status and results achieved by these programs. There are no directly comparable provisions in H.R. 2454 . Section 175 of Subtitle H of H.R. 2454 does provide for a government program to help develop and demonstrate high efficiency natural gas burning combustion turbines, for use in combined cycle power plants. The section directs the Secretary of Energy to carry out a multiyear, multiphase program of research, development, and technology demonstration that ultimately will lead to gas turbine combined cycle efficiency of 65%. H.R. 2454 contains several provisions relating to electric power transmission that have no counterparts in S. 1733 . These provisions are briefly summarized below. For more detail see CRS Report R40643, Greenhouse Gas Legislation: Summary and Analysis of H.R. 2454 as Passed by the House of Representatives , coordinated by [author name scrubbed] and [author name scrubbed]. Subtitle F of Title I of H.R. 2454 deals with transmission planning and permitting. The subtitle provides for the following in respect to transmission planning: Establishes a national transmission planning policy, which states that transmission planning "should facilitate the deployment of renewable and other zero-carbon and low-carbon energy sources for generating electricity to reduce greenhouse gas emissions while ensuring reliability, reducing congestion, ensuring cyber-security, minimizing environmental harm, and providing for cost-effective electricity services throughout the United States…." Directs the Federal Energy Regulatory Commission to define electric transmission planning principles, based on the national policy, which can be used by planning entities. FERC is to facilitate coordination between state, regional, and industry transmission planning entities. In respect to permitting, the bill grants FERC new federal siting and permitting authority within the Western Interconnection. This authority to supersede state permitting decisions applies only to proposed transmission projects that meet certain criteria, including interstate projects "identified as needed in significant measure to meet demand for renewable energy." H.R. 2454 includes several provisions aimed at supporting development and installation of smart grid technologies (see Title I, Subtitle E). The bill would direct the Department of Energy and Environmental Protection Agency to identify products that could be cost-effectively equipped with smart grid capability. The legislation would also direct the Federal Trade Commission to initiate a rulemaking to determine whether smart grid information, such as potential dollar savings to the consumer, should be added to ENERGY GUIDE product labels. (ENERGY GUIDE is an existing federal program for labeling energy efficient products.) The legislation would establish requirements for electric power retailers to reduce their peak loads using smart grid and other energy efficient technologies; and would modify an energy efficiency public information program authorized by the Energy Policy Act of 2005 (EPACT05) to make it into a smart grid and energy efficiency information program. H.R. 2454 would also modify an EPACT05 energy efficiency appliance rebate program to add appliances with smart grid capabilities. Additionally, H.R. 2454 would require state regulatory authorities and self-regulating power suppliers (such as municipal utilities) to consider implementing standards intended to ensure that utility smart grid systems would be compatible with plug-in electric drive vehicles. Section 152 of Subtitle F of H.R. 2454 provides for net metering of federal agencies. Net metering is a ratemaking concept intended to encourage the development of "distributed generation" (i.e., electricity generated at the customer's site, possibly, but not necessarily, using renewable energy). Net metering is intended to make distributed generation more economical by requiring the utility that supplies electricity to a facility to also take any electricity generated by that facility, such as from rooftop solar panels or an on-site diesel generator. The ultimate utility bill to the facility is reduced by the amount of electricity supplied to the power company. Section 152 amends the Public Utility Regulatory Policies Act of 1978 to require state regulatory authorities to consider ordering utilities under their jurisdiction to implement net metering for federal facilities. It also requires non-regulated utilities (such as many municipal utilities) to make the same evaluation.