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January 23, 2012 - 9:42am

By Steven Nadel, Executive Director


ACEEE is preparing a series of working papers on how energy efficiency issues might be addressed as part of tax reform. We call them working papers because we are soliciting feedback and comments on these drafts so that our analyses and proposals can be refined. We plan to release final versions of these papers as part of a larger report later this year. We also welcome feedback on additional tax-related topics touching energy efficiency that might be useful to address.

Our tax code is widely criticized as being too complicated, and it has been more than 20 years since the tax code has had a major overhaul. Many proposals for reform call for fewer tax brackets and eliminating many current tax breaks, creating a simpler code with lower tax rates. For example, the President’s debt commission (officially called the National Commission on Fiscal Responsibility and Reform) in its December, 2010 report suggested eliminating most current tax breaks and reducing the number of tax brackets from five to three. Under this plan, income tax rates would fall to 12, 22, and 28%, down from present rates that peak at 35% (and down from the even higher rates scheduled to take effect in 2013 after the “Bush tax cuts” expire).

However, a number of people have suggested that even these rates are too high. The budget for 2012 approved by the House of Representatives on April 15, 2011 called for consolidating current tax brackets and reducing the top bracket from 35% to 25%. But as rates are lowered, either spending must be cut further (a difficult and contentious undertaking) or some additional revenue sources must be found.

Today we issued the first of our working papers, entitled Should the U.S. Consider a Modest Emissions Fee as Part of a Strategy to Lower Marginal Tax Rates? In this paper, we discuss reducing marginal tax rates, which could be offset by some additional revenue. In facing this question, we think it is useful to go back to first principles. The government needs revenue, and there are many options for collecting it. Our present tax system largely taxes things that result from productive economic activity—wages, non-wage income, and corporate profits. An alternative would be to collect some revenue from things that produce negative economic effects, such as cigarettes, alcohol, and as we propose, pollution.

This is not a new concept. The idea that taxes can be used to discourage activities that produce negative externalities was originally suggested in 1920 by the economist Arthur Pigou, then the head of the economics department at the University of Cambridge in England. In economics literature, these are now commonly known as Pigovian taxes. Many prominent economists and politicians have spoken in favor of using Pigovian taxes to regulate pollution. As the economist Milton Friedman noted in a 2005 interview: “There is a role for government and the question is what are the means that you use. And the answers of a free market environmentalist is you use market mechanisms. Instead of setting quantitative limits on pollution, you impose a tax.” And as David Frum, a speechwriter for President George W. Bush, said in a 2006 Wall Street Journal op-ed: “Democrats have made a great theme of ‘energy independence.’ The president has likewise denounced America's ‘addiction to oil’ and often presented nuclear power as a crucial element of an ideal energy policy. What if he baited the Democrats with some kind of energy tax (or, better, a carbon tax—which exempts nuclear-generated energy) in exchange for permanent cuts in taxes on work, savings and investment? ‘Tax waste, not work’ is not a bad slogan.”

We are not suggesting that all revenues be collected from Pigovian taxes, but rather that an increased portion of the current tax burden come from these taxes. We start from a proposal examined by the Bipartisan Policy Center Debt Reduction Task Force and look at further details, such as how much tax rates could be lowered, and the impacts of the emissions fees and investments in low-emissions technologies. We also examine concerns that any new tax or fee would be easy to increase in the future and suggest ways to address this concern.

We encourage you to download and read the paper—it’s only six pages not counting references. And we  welcome your  comments on it. Comments and suggestions can be sent to taxreform@aceee.org. All comments will contribute to developing our working papers and will not be shared as public information.


Climate Change Policy, Economic Development, Economic Recession & Recovery, National Policy

January 18, 2012 - 10:02am

By Jacob Talbot, Buildings Program Analyst


This is an exciting time for water heating efficiency. It was not so long ago that consumers had few options when their water heater failed beyond purchasing a new version of the same electric-resistance or atmospherically-vented storage water heater they had previously owned. Now, consumers can chose from a wide array of storage, tankless, and hybrid (small tank units that heat water on-demand) models. But high efficiency products are still on the fringe—most water heater sales are for conventional storage units.

In our recent study of emerging technologies in the water heating sector, we found that there are many underutilized technologies that could provide significant energy and water savings. This finding led us to ask, “What efforts are being made to hasten market adoption of these promising technologies?” In our latest report, Market Transformation Efforts for Water Heating Efficiency, we assessed current utility-sponsored programs targeting high efficiency water heating equipment and found that many programs are not reaching the full cost-effective energy efficiency potential of modern technologies. In other words, many of these programs focus on products that achieve only small incremental savings above federal minimum efficiency standards, overlooking the emerging technologies that offer 30-50% energy savings (e.g., electric heat pump and condensing gas water heaters). Such programs could be inhibiting emerging technologies from gaining market share.

Utility incentive programs have long served a pivotal role in market transformation efforts for high efficiency appliances. Not only do the financial incentives help homeowners justify investing in better equipment, utilities also help advertise the availability of high efficiency equipment, and the endorsement of the utility company offers consumers reassurance about the equipment’s performance. Coupled with high efficiency labeling programs, such as ENERGY STAR, utility-sponsored programs help to assure consumers that they are making smart, cost-effective decisions. What we found in our evaluation, however, is that for high-use customers, higher efficiency water heaters, such as condensing gas water heaters, are more cost-effective than some of the products frequently featured in the programs (e.g., 0.67 EF ENERGY STAR-qualified gas storage water heaters). This is true despite higher equipment costs. It will be very important for consumers to understand the cost effectiveness of emerging technologies in order to increase market penetration of these products and bring down costs.

We found that incentives for products that are only marginally better than minimum standards, such as 0.62 EF gas storage and 0.94 EF electric storage water heaters, virtually eliminate incremental costs, and could steer consumers away from purchasing higher efficiency products. These lower efficiency models offer savings of only about 5% compared to condensing gas and heat pump water heaters, with savings in the range of 40-50%. Directing consumers to lower efficiency products constitutes a big lost opportunity for energy savings, as water heaters typically last about 13 years.

While some utility programs may retard market transformation, we found several programs offering incentives for heat pump and condensing gas water heaters, in addition to equipment to improve distribution system performance, such as drain water heat recovery devices. While in the minority, these programs recognize the large energy-saving potential of high efficiency equipment and offer large incentives, ranging from about $200-500, to encourage consumers to invest in efficient equipment. Considering that the emerging technologies we evaluated hold less than 2% market share, these programs serve as a valuable step toward increasing awareness and sales. We’re happy to see these utility-sponsored programs leading the way with incentives for emerging technologies and hope to see more utilities follow suit in the near future.

To read more about our study on market transformation efforts for high efficiency water heating equipment, download the report.


Appliance Standards, Cost-Effectiveness Tests, Efficiency Potential & Market Analysis, Emerging Technologies & Practices, Financial Incentives for Energy Efficiency, Market Transformation, Utilities, Water Heating, Residential, Commercial

January 17, 2012 - 11:04am

By Michael Sciortino, Policy Analyst


As our Executive Director Steven Nadel pointed out in a recent blog post, energy efficiency had mixed success in 2011. At the state level, however, we saw some nice improvements, many of which were reflected in our 2011 State Energy Efficiency Scorecard report. Utility-sector investments in energy efficiency programs are increasing, building energy code adoption is rising, and more states are adopting policies and programs to promote energy-efficient transportation systems. While the year’s developments are too numerous to detail here, below we share some of the major stories of 2011. For a complete read on what is happening in the states, check out our State Energy Efficiency Policy Database and our series of state-related blog posts: The State Current.

Northeast/Mid-Atlantic

Massachusetts, Vermont, New York, and Rhode Island continue to anchor energy efficiency in the Northeast. Each state has adopted aggressive energy efficiency goals of around 2% of sales per year and in 2011 each state’s programs achieved impressive levels of savings. New York has also reaffirmed its commitment to energy efficiency as its main energy agency, the New York State Energy Research and Development Authority (NYSERDA), submitted a proposal for a new set of programs that would shift its focus to driving technology innovation and adoption of advanced building codes. The state Public Service Commission is also attempting to revise its regulatory and program framework to help the state achieve its aggressive Energy Efficiency Resource Standard (EERS) policy.

Connecticut regained its footing in 2011. After energy efficiency funding was diverted to shore up the state budget deficit in 2010, newly-elected Governor Dannel Malloy signed a bill restoring funding to the Connecticut Energy Efficiency Fund in 2011. Governor Malloy is eager to move his state to the top of the Scorecard.

Down the coast, Pennsylvania utilities successfully met the first phase of their state’s EERS policy, and in Washington, D.C., a third-party energy efficiency program administrator got up and running. West Virginia, a state that has historically placed low in our Scorecard rankings, is also beginning to seriously consider building energy codes and improved utility-sector energy efficiency programs. Delaware and Maryland remain far behind in implementing their aggressive EERS targets. The Delaware EERS Workgroup published a Report in 2011 underscoring the numerous challenges the state must address to implement its EERS, including the need for a sustainable and robust funding source. Maryland is much farther along than Delaware, but as the Maryland Public Service Commission (PSC) pointed out in December, there is much work to be done. The Maryland PSC directed the state’s utilities to identify additional efficiency programs to make up the gap between their current plans and state law, which requires utilities to achieve 10% savings by 2015.

The Regional Greenhouse Gas Initiative (RGGI) also came under fire from numerous sides. The carbon auction proceeds from RGGI fund energy efficiency programs in many states, and recent studies have shown the program to be highly beneficial for the states. However, New Jersey intends to pull out of the compact, and similar measures were introduced but defeated in New Hampshire and Maine.

For more information on the Northeast, read the Northeast Energy Efficiency Partnership 2011 Regional Roundup Report.

South/Southeast

In the Southeast, the states are making important strides. The Mississippi Public Service Commission has proposed an energy efficiency program planning process for its major utilities. North Carolina and South Carolina will likely see more energy efficiency programs in 2014-2018 as the merger between Duke Energy Carolinas and Progress Energy Carolinas has resulted in a Settlement Agreement that calls for the implementation of more energy efficiency programs. Alabama stood out in this year’s State Energy Efficiency Scorecard as a “most improved state” as it looks set to adopt the 2009 IECC building energy codes. In Louisiana, the Public Service Commission issued a proposed rulemaking on energy efficiency programs in the fall, and the New Orleans City Council, which has utility regulatory authority for the city, passed a resolution in July that established an Integrated Resource Planning (IRP) process. The Tennessee Valley Authority (TVA) and Georgia Power both found that energy efficiency acts as a critical resource when conducting their IRPs. Both utilities have implemented new programs over the past year. In Arkansas, utilities began to implement programs following a series of PSC decisions in late 2010 and the Commission issued guidelines for industrial self-direct programs. The Texas legislature shifted the state EERS to a percent of annual sales basis, with the target to eventually reach 0.4% of sales. The legislature also broadened the range of programs utilities could use to reach their targets. Utilities and regulators in Florida, however, took a step backwards by failing to fund programs at levels that would allow them to reach their energy efficiency targets of around 3% cumulative savings by 2020.

Midwest

The Midwest featured three of our most improved states in this year’s State Energy Efficiency Scorecard. Michigan and Illinois both outpaced their neighbors in actual savings from programs implemented to meet their respective Energy Efficiency Resource Standards. Other states with recently passed EERS policies like Indiana and Ohio have programs planned or in place that will produce the savings necessary to start catching up with Michigan and Illinois in our Scorecard. Nebraska also climbed in the rankings as it adopted 2009 IECC building energy codes; however, the state still falls behind much of the region. Utilities in South Dakota have a healthy portfolio of energy efficiency programs underway, which should begin to make a solid impact on the state’s score in 2012. Meanwhile, Wisconsin risks losing its position as a leader in electric sector energy efficiency. Shortly after multiyear funding and savings targets wereapproved by a Joint Committee of the state legislature, the state essentially dismantled these steps by limiting funding to its program administrator, Focus on Energy, to 1.2% of revenues, which will not be sufficient to meet the goals laid out in the order. Further south, utilities in Missouri are developing plans to work within the PSC's new efficiency cost recovery guidelines, and Kentucky is undergoing stakeholder processes to jumpstart utility-sector energy efficiency programs.

West

Utilities in the Southwest continue to implement energy efficiency programs supported by strong policies. Commissions in New Mexico and Arizona strengthened the business model for energy efficiency by approving performance incentives and decoupling mechanisms. Xcel Energy in Colorado has cemented itself as an energy efficiency leader in the Mountain States by adopting even more aggressive energy efficiency programs and targets for 2012-2013. California dropped in our Scorecard rankings to #2, and there are concerns the state may be slipping after its legislature failed to re-authorize a systems benefits charge that funds energy efficiency programs. However, utilities in California remain steadfastly committed to the energy efficiency resource, as does the California Public Utility Commission (CPUC), which is considering ways to replace the systems benefits charge and also recently introduced a proposal that would create the nation’s first statewide on-bill repayment (OBR) program for energy efficiency and renewable energy upgrades to be financed entirely by third parties.   

Looking Forward to 2012

Overall, the states made good strides in 2011 advancing energy efficiency. Out of 50 points possible in our Scorecard report, the average score was 20.3, an increase of two points over the 2010 results. The states are poised for continued advancements in energy efficiency policy and programs in 2012. Numerous states are only in the nascent stages of utility-sector program implementation, for example, and should see their scores improve as the programs mature. There is plenty of room for progress—however, there is also opposition to energy efficiency that could set states back. The energy efficiency community must continue to make the convincing argument that energy efficiency is an abundant, affordable resource that provides a multitude of economic and environmental benefits.


Building Codes, Energy Efficiency Program Funding, Energy Efficiency Resource Standards, State Current, Utility Regulation & Policy, State Policy

January 10, 2012 - 4:41pm

By R. Neal Elliott, Associate Director for Research


A few weeks ago I presented to state regulatory commissioners at the NARUC fall meeting, and many of the questions coming from utility commissioners were about combined heat and power (CHP). This attention on CHP is not isolated. Congressional offices have been trying to develop legislative strategies to encourage CHP; environmental groups are looking at it as a bridge to a low-carbon economy; large industrial consumers are looking at it as a path toward modernization of the manufacturing base; and utilities are starting to consider it as an alternative to building new generation power plants. The 15-year-old goal of increasing CHP’s visibility that led to a national CHP strategy and the founding of the U.S. Clean Heat and Power Association (USCHPA) are finally being realized: CHP is finally a hot topic. The question now is: is CHP ready for primetime or will we need a new business model to take advantage of this historic opportunity?

For the first time in several decades we are entering a period of significant investment in new generation and transmission. Several forecasters have projected that we could see on the order of 150 GW of new conventional generation and associated transmission assets by the end of the decade. About 40 GW of this new capacity will likely replace retiring coal plants. These plants will likely be shut down due to environmental regulatory changes and shifts in fuel markets that make the continued operation of some older power plants uneconomic. The balance of new generation capacity will likely be deployed to meet load growth and regional shifts in demands due to changes in our economy.

These utility supply investments would raise electricity rates significantly, perhaps 20% or more, to recover the new capital costs. Public officials are loath to approve these rate increases in the current economic environment, and are looking for lower-cost alternatives to expand supply and meet new demand. Reports such as the State and Local Energy Efficiency Action Network’s Industrial Energy Efficiency and Combined Heat and Power Blueprint that suggest that 40 GW of new CHP capacity is achievable by 2020 at half the cost of new gas-fired electric-only generation have attracted the attention of policy leaders. Similarly, we’ve seen industrial leaders embrace the idea of CHP as a way to modernize manufacturing while containing potential rises in electricity rates.

However, the CHP market is not currently in the position to take advantage of this shift in electricity markets, and is viewed as soft by developers in most states. This market softness comes despite significant advances in CHP policies at the national and state level: a 10% federal investment tax credit enacted in 2008, complimentary incentives in a number of key states, and even support for CHP at the Federal Energy Regulatory Commission (FERC). This market softness hasn’t always been the case. Following a period of robust expansion beginning in the mid-1990s, installed CHP capacity increased from about 46 GW in 1996 to over 80 GW by the mid-2000s. It stalled at this level, and now stands at about 86 GW, delivering over 12% of U.S. electricity supply annually.

The market’s lack of robustness results from a number of factors, many related to market conditions rather than CHP-friendly policies alone. High and volatile natural gas prices coupled with comparably stable electricity prices increased the calculated future financial risk for CHP projects. As the economy softened in late 2007 and into 2008, private sector investment declined, further discouraging any investments at all. And with the softening economy, energy demand was depressed, making CHP investments even less attractive as energy prices fell.

This brings us to the current market situation today. Even now as the economy is pulling itself out of a recession, private sector investors are setting fairly short-term investment horizons, usually of four years or less. Since CHP investments are major, long-term projects with typical economic lives of 10 years or more, we’re seeing a fundamental mismatch between the private sector financial thresholds and the required investment horizon for CHP. The only place we are not seeing this mismatch is the institutional market of universities, hospitals, and public campuses, often in conjunction with district energy systems. The International District Energy Association (IDEA) reports significant interest and activity in CHP among its members. This activity is occurring in part because of the longer-term investment horizons of these institutions. They are prepared to invest now to realize the substantial energy cost savings and risk reductions available from CHP over the long run.

For private sector investors to follow these institutions the CHP community needs to embrace a new business model that is able to capture the opportunity to lock in long-term reduced electricity and energy costs during this period of generation capacity expansion. A logical path to explore would be for utilities, which are similar to institutions in their investment horizons, to play a role in developing or financing CHP projects. Some utilities are beginning to explore this idea, but it will require a substantial shift in the regulatory business models for our electric utility companies, as a recent ACEEE white paper discusses.

Unfortunately, this shift will require significant discussion among groups that haven’t historically exhibited strong lines of communications. Over the past six months, I have been party to discussions among a diverse range of stakeholders concerning CHP, ranging from CHP advocates to environmental groups to industrial leaders to utilities to policymakers. What has struck me is the inability of these groups to reach outside their networks to engage others who are critical to exploring and deploying these alternative business models. These networks lack a single forum. Such a forum could convene all stakeholders to discuss a path forward that would benefit all parties and help us all realize the full potential of CHP to improve the U.S. economy, our energy security, and our environment.

Photo by Warren Gretz, NREL staff photographer


Combined Heat and Power (CHP), Distributed Generation, Electricity, Industrial Energy Efficiency Programs, Interconnection Standards, Manufacturing, National Policy, Utility Regulation & Policy, State Policy, Industrial