The future of utility customer-funded energy efficiency programs in the USA: projected spending and savings to 2025
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We develop projections of future spending on, and savings from, energy efficiency programs funded by electric and gas utility customers in the USA, under three scenarios through 2025. Our analysis, which updates a previous LBNL study, relies on detailed bottom-up modeling of current state energy efficiency policies, regulatory decisions, and demand-side management and utility resource plans. The three scenarios are intended to represent a range of potential outcomes under the current policy environment (i.e., without considering possible major new policy developments).
By 2025, spending on electric and gas efficiency programs (excluding load management programs) is projected to double from 2010 levels to $9.5 billion in the medium case, compared to $15.6 billion in the high case and $6.5 billion in the low case.
Compliance with statewide legislative or regulatory savings or spending targets is the primary driver for the increase in electric program spending through 2025, though a significant share of the increase is also driven by utility DSM planning activity and integrated resource planning.
Our analysis suggests that electric efficiency program spending may approach a more even geographic distribution over time in terms of absolute dollars spent, with the Northeastern and Western states declining from over 70 % of total USA spending in 2010 to slightly more than 50 % in 2025, and the South and Midwest splitting the remainder roughly evenly.
Under our medium case scenario, annual incremental savings from customer-funded electric energy efficiency programs increase from 18.4 TWh in 2010 in the USA (which is about 0.5 % of electric utility retail sales) to 28.8 TWh in 2025 (0.8 % of retail sales).
These savings would offset the majority of load growth in the Energy Information Administration’s most recent reference case forecast, given specific assumptions about the extent to which future energy efficiency program savings are captured in that forecast.
The pathway that customer-funded efficiency programs ultimately take will depend on a series of key challenges and uncertainties associated both with the broader market and policy context and with the implementation and regulatory oversight of the energy efficiency programs themselves.
KeywordsEnergy efficiency programs Utility Ratepayer Targets Natural gas Energy efficiency resource standards
Electric and natural gas energy efficiency in the USA is pursued through a diverse mix of policies and programmatic efforts. These efforts include federal and state minimum efficiency standards for electric and gas end-use products; state building energy codes; a national efficiency labeling program (ENERGY STAR®); tax credits; and a broad array of largely incentive-based programs for consumers, funded primarily by electric and natural gas utility customers (Dixon et al. 2010).1 Over the past four decades, policy support and utility customer funding of energy efficiency programs, in particular, has ebbed and flowed.2 Utilities first launched substantial programs in the wake of the 1973 energy crisis, and those programs grew and matured with the expansion of integrated resource planning and demand-side management during the 1980s and 1990s (Nadel 1992). Spending on energy efficiency by utilities then declined sharply in many states in the late 1990s, with the restructuring of the electricity industry. However, the western energy crisis of 2000–2001 brought renewed attention to energy efficiency as a critical element that contributes to managing and containing costs for electric utility customers.3
Since then, many state regulatory agencies and legislatures have sought to prioritize energy efficiency, in some cases strengthening and supplementing pre-existing policies by requiring comprehensive electric and gas system resource planning, developing funding mechanisms and energy savings targets, and creating business incentives for program administrators to deliver energy efficiency to customers. In some states, regulators have also extended demand-side planning, savings targets, or business incentive mechanisms from the electricity sector to large regulated natural gas utilities.
A variety of organizations and analysts have examined trends in utility customer-funded energy efficiency programs in the USA. These include efforts to document historical and recent trends in spending, savings, or both Nadel 1992; Sciortino et al. 2011; Cooper and Wood 2012; CEE 2012), as well as estimates of the projected impact of individual policies related to utility customer-funded energy efficiency (Nowak et al. 2011) or in particular regions (Hopper et al. 2008). Yet other studies have sought to estimate the potential savings that could be obtained through customer-funded efficiency programs, including an innumerable number of such studies conducted for individual utilities or states, as well as several national studies (EPRI 2009). The present study builds upon the body of existing literature by comprehensively assessing the potential impact of the full suite of policies and market conditions relevant to the future of utility customer-funded energy efficiency programs in the USA, updating an earlier LBNL analysis (Barbose et al. 2009).
Specifically, we project future spending on, and savings from, U.S. electric and gas efficiency programs to 2025 under low, medium, and high scenarios. The projections are based on a detailed, bottom-up review and modeling of all relevant state policies and legislation, regulatory decisions, and utility integrated resource and demand-side management plans. The three scenarios are intended to represent a range of potential outcomes under the current policy environment, given uncertainties in policy implementation and in the broader economic and policy environment (e.g., utility business models, the extent to which energy efficiency is a policy priority, and concerns about rate impacts). The three scenarios are not intended to encompass major new federal policy developments, which could naturally expand the range of potential outcomes beyond those modeled here.4 Scenario definitions and assumptions were also informed by interviews with regional and national energy efficiency experts, program administrators, regulatory staff, and other industry stakeholders. Based on the quantitative analysis of projected spending and savings under varying policy implementation scenarios, we identify and discuss the broader themes and issues that will influence which of the potential projections are most likely to transpire.
The study has relevance to a broad range of audiences: utilities and other entities responsible for administering customer-funded efficiency programs and the state regulatory agencies responsible for overseeing their implementation; policymakers, planners, and industry analysts seeking to understand the potential impact of these programs on the broader electricity market or their implications for other policies; and the energy services industry seeking to understand market trends and opportunities. While this study focuses on the USA, the analysis also has relevance to policymakers abroad where energy and environmental policies may require the development of specific long-term energy savings goals and/or funding mechanisms for voluntary incentive-based programs, such as those that are prevalent in the USA. For example, the set of potential trajectories of U.S. efforts potentially offers a window on the prospects and issues raised by the 2012 European Union Energy Efficiency Directive (Directive 2012/27/EU), in which the European Parliament and Council committed member states to adopting efficiency targets and submitting implementation plans consistent with a EU-wide target of saving 20 % of the projected primary energy consumption in 2020 (Boonekamp 2011).
The remainder of the paper is organized as follows. “Recent policy developments and trends” section provides an overview of the key policy drivers that influence future efficiency program spending and savings, and summarizes current trends in spending on energy efficiency programs across states. Our modeling approach for capturing policy and market influences on future spending and savings for electric and gas efficiency programs is described in the “Analytical approach” section. The results of our analysis are presented in the “Results” section. In the “Discussion of key issues and uncertainties” section, we identify key challenges and discuss significant uncertainties in market and policy drivers that may influence the path forward for customer-funded efficiency programs.
Recent policy developments and trends
Over the past decade, an increasing number of states have adopted policies that encourage or require utility customer-funded energy efficiency programs. In this section, we summarize recent trends in the development of these policies and the current and historical spending levels across states.
Policy drivers for utility customer-funded energy efficiency programs
Policy drivers for customer-funded energy efficiency program activity
Key policy drivers for energy efficiency spending and savings
Applicable to electric efficiency programs
Applicable to natural gas efficiency programs
Energy Efficiency Resource Standard (EERS)
AZ, CA, CO, HI, IL, IN, MD, MI, MN, MO, NM, NY, OH, PA, TX
CA, CO, MI, MN, NY, IL
Energy efficiency eligibility under state RPS
HI, MI, NC, NV, OH
Statutory requirement that utilities acquire all cost-effective energy efficiency
CA, CT, MA, RI, VT, WA
CA, CT, MA, RI, VT, WA
Systems benefit charges
CA9, CT, DC, MA, ME, MT, NH, NJ, NY, OH, OR, RI, VT, WI
CA, DC, ME, MT, NJ, NY, RI, WI
Integrated resource planning
34 States (primarily in the West and Southeast) and TVA
17 States (primarily in the West and Northeast)
Demand Side Management plan or multi-year energy efficiency budget
21 States (primarily in the Northeast and Midwest)
A number of these policy drivers are relatively recent, most notably energy efficiency resource standards (EERS), which have thus far been adopted in 15 states and require utilities to achieve minimum energy efficiency savings targets over a lengthy period of time.5 Similarly, several others states have adopted broader renewable portfolio standards (RPS) or alternative energy standards under which energy efficiency is a qualifying resource. Many of these EERS policies and RPS policies with energy efficiency allowances have been enacted in states that previously had not aggressively pursued customer-funded energy efficiency and have therefore required rapid development of the regulatory and administrative structures necessary to implement and oversee sizable energy efficiency program portfolios. Another recent policy development in a number of states, all of which have offered large-scale energy efficiency programs for more than a decade, is the development of statutory or regulatory requirements that utilities acquire “all cost-effective” energy efficiency. In these states, program administrators or regulatory staff may then conduct studies that estimate the long-term, cost-effective savings potential and then propose annual or multi-year savings targets and budgets in order to capture this potential over a defined time period.
Other facets of the energy efficiency policy landscape are less recent. System benefit charges, which exist in 14 states and were typically established more than a decade ago as part of larger electric industry restructuring processes, serve to set an approximate floor on energy efficiency program spending via a non-bypassable surcharge on customers’ utility bills. Integrated resource planning (IRP) also exists in many states, whereby utilities are required to plan for the long-term needs of their customers by considering and assessing a broad range of resource options, including energy efficiency resources. Depending upon the manner and extent to which utilities are required to assess energy efficiency options, the IRP may culminate in a 10- to 20-year plan with specified levels of energy efficiency resource acquisition. Finally, utilities in many states are required to regularly submit a demand-side management (DSM) plan to their state regulator, proposing a specific portfolio of programs that meet cost-effectiveness guidelines and other policy objectives, typically on a 1- to 3-year cycle.
Although IRP and DSM planning have both been utilized for more than 20 years, their application has expanded somewhat in recent years as a result of policy spillover or cross-border effects from other states within a given region. For example, Arkansas regulators developed a step-by-step energy efficiency program development template that has been cited as a policy influence in other southern states (e.g., Mississippi and Alabama).6 Multi-state utilities also are developing territory-wide efficiency programs designed to meet one state’s mandates, in effect carrying that state’s energy saving policies de facto into neighboring states.7 Lastly, the move by the Tennessee Valley Authority (TVA)8 to set savings targets through its IRP, and to offer programs and encourage its member distributors to offer programs, is expected to spread the pursuit of energy efficiency across the seven states where it provides wholesale power.
In addition to the energy efficiency policy drivers summarized in Table 1, other broad market and policy dynamics may also play a critical role in shaping the trajectory of future spending and savings from customer-funded energy efficiency programs. We discuss several of these factors in the “Broader market and policy context” section, including the timing and pace of the economic recovery, the long-term trend in natural gas prices, the stringency of future federal and state minimum efficiency standards for appliances and building codes, and the outcome of federal air emissions regulations.
Current and historical spending on utility customer-funded energy efficiency programs
2010 Expenditures for utility customer-funded energy efficiency (ee) programs
Combined electric EE spending ($M)
Electric and gas EE spending ($M)
Gas EE spending ($M)
Top 10 states
% of U.S.
Remainder of U.S.
% of U.S.
In particular, the majority of funding for electric efficiency programs is concentrated in California, the Pacific Northwest (OR, WA), and the Northeast (MA, NJ, NY, CT), all states with a long history of commitment to energy efficiency. Other states, many located in the Midwest (e.g., OH, PA, IL, IN, and MI), are in the process of ramping up program spending, often driven by long-term electricity savings targets. The top ten states, in terms of absolute dollar expenditures, account for about 70 % of 2010 spending on electric energy efficiency programs. Program administrators in the leading states with the highest per capita energy efficiency spending typically offer a comprehensive portfolio of programs tailored to residential, commercial, and industrial customers that utilize a variety of designs and intervention strategies (e.g., technical assistance to end users and trade allies, incentives to customers to buy down the cost of high-efficiency equipment, and incentives to upstream manufacturers and retailers to stock and distribute high-efficiency products).
Gas efficiency programs are less widespread than electric programs, and thus, funding is even more highly concentrated in a small number of states, where the top ten states account for almost 80 % of the national budget for gas efficiency programs. Specifically, gas efficiency spending is concentrated in about a dozen states in various regions: NY, MA, and NJ in the Northeast; IL, MI, IA, MN, and WI in the Midwest; and CA, OR, and UT in the West. Most southern utilities have modest retail gas sales or function largely as distribution entities that convey “transportation gas,”11 and they consequently spend little on gas efficiency programs. Nationally, gas efficiency program budgets are dominated by residential and low income programs, together comprising 68 % of total program expenditures in 2010 (CEE 2012), which is quite different from the program mix for electric efficiency programs.12
We developed low, medium, and high case projections of electric and natural gas efficiency program spending to 2025, as well as accompanying projections of electric program energy savings.13 These projections are based on a state-by-state review of current policies, regulatory decisions, utility IRPs and DSM plans, and other key regulatory and planning documents, further supported through interviews with state PUC and utility staff and regional energy efficiency experts. The projections are intended to represent alternative pathways for the future evolution of energy efficiency programs, given the current set of policies in place and the larger market and policy environment in which programs operate. As explained further below, we took different approaches to developing projections for electric and gas energy efficiency program spending.14 These methodological differences reflect both that enabling efficiency policies are more prevalent among electric utilities compared to gas utilities, and that the level of development and experience with administering electric efficiency programs is much greater than for gas programs.
Electric energy efficiency program spending and savings projections
Scenario assumptions for electric energy efficiency projections
TX IOUs meet minimum EERS targets. TVA savings based on 2010 IRP “Baseline Portfolio.” NC IOUs achieve only as much savings as can be applied towards their RPS. Utilities maintain spending at the level in the last year of recent DSM plans (in terms of percentage of revenues).
TX IOUs maintain savings at current levels (0.2 % of sales), exceeding EERS targets. FL IOUs ramp up savings to 0.3 % of sales. IRP savings targets are achieved (TVA, KY, GA). Otherwise similar to low case.
TX utilities ramp up savings to 0.3 % of sales, offsetting 50 % of demand growth. FL IOUs ramp up to long-term savings targets established by regulators (0.48 % of sales in 2019) and to 0.75 % by 2025. TVA and IOUs in GA, NC, and SC ramp up savings to roughly 1 % of retail sales. MD utilities meet state EERS goals.
IL, IN, and OH utilities fall short of EERS targets (e.g., due to cost caps or opt-out), but MI and MN utilities fully meet their more-modest EERS targets. IA utilities maintain current spending levels, and WI spending is equal to current legislative cap of 1.2 % of revenues.
EERS targets are achieved in most cases, one exception being IL, where cost cap is eased but not to the extent required to meet ultimate targets. IA spending continues at the level in the last year of the most recent DSM plans. WI spending rebounds to 1.7 % of revenues, half way between current legislative cap and historical peak.
All states reach savings of roughly 1.5 to 2 % of retail sales, meeting or exceeding EERS targets by varying degrees.
CA IOU savings are based on 90 % of market potential, as estimated in Navigant Consulting Inc. 2012, which decline from current levels. AZ and NM utilities achieve EERS targets. Many utilities in the Northwest achieve savings equal to 60 % of NPCC’s 6th Power Plan conservation targets, with remainder achieved through codes and standards. Utilities in other states achieve savings based on most recent IRP or maintain constant savings based on the final year of their most recent DSM program plan, whichever is less.
CA IOU savings are based on 110 % of market potential in Navigant Consulting Inc. 2012. CO utilities achieve EERS targets. In the Northwest, utility savings equal 75 % of NPCC conservation targets, with remainder achieved through codes/standards. Utilities in most other states achieve savings based on most recent IRP or maintain constant savings based on the last year of their most recent DSM program plan, whichever is greater.
CA IOU savings are based on 130 % of market potential in Navigant Consulting Inc. 2012. AZ IOUs meet EERS targets without reliance on retroactive credit for historical programs, and SRP achieves similar savings levels. CO is same as medium case. In the Northwest, utility savings equal 85 % of NPCC conservation targets, with remainder achieved through codes/standards. Utilities in many other states achieve savings of roughly 1.5 % of retail sales.
Spending levels in most states remain flat at roughly the statutory minimum (constituting a decline from current spending in some states) and/or continue at current funding levels. In NJ, spending declines by more than 50 % from current levels, as reliance shifts to revolving loan funds, with program spending equal to roughly 70 % of the levels specified in the recent RFP for program administration.
Spending in most states, as a percentage of revenues, remains flat at the level in the final year of the most recent energy efficiency program plan. NY meets its EERS target for 2015, but spending thereafter reverts to the 2010-2015 average. PA spending rises to current cap. NJ programs shift to revolving loan funds, but spending levels declines less severely than low case to reflect a more successful transition to financing model.
New England IOUs capture all cost-effective energy efficiency, up to a stipulated spending cap (10 % of revenues for MA, RI, and VT; 6.5 % for CT). NY meets its EERS target for 2015, and spending thereafter continues at 2015 levels. Savings in other states rises to 1-2 % of retail sales.
Spending increases to 0.3 % of revenues above current levels
Spending increases to 0.5 % of revenues above current levels
Spending increases to 0.8 % of revenues above current levels
Although the scenario definitions were developed on a state-by-state basis, with consideration of the specific policy and market context in that state, the low, medium, and high scenarios can be characterized in broad terms. At a conceptual level, the low scenario represents a less prominent role for energy efficiency as a resource in many states as program spending remains at current levels or increases very modestly (or decreases in a few states) in subsequent years. The medium scenario reflects a future in which states that historically have been leaders in energy efficiency continue down that path and in some cases expand the role of energy efficiency as a resource, while other states are fairly successful in ramping up their energy efficiency programs to meet legislative saving targets. Note that in the medium scenario, our estimates of future savings account for constraints that may limit the ability of program administrators to achieve savings targets—e.g., ability for energy efficiency services infrastructure to ramp up quickly in early years and rate or spending caps that limit program spending increases in later years. The high scenario reflects a future in which many states establish a very prominent role for energy efficiency as a resource: states with EERS statutes are assumed to meet savings targets (and overcome constraints), states in each region are inclined to follow the example (and goals) established by leading states in that region, and those states that are currently “uncommitted” are assumed to adopt policies that lead to savings in 2025 of roughly the national average savings targets achieved by utilities currently.
Gas energy efficiency program spending projections
For the purpose of developing projections of utility customer funding of gas efficiency programs, we first grouped states into three categories: Tier I consists of the 13 states that comprise more than 80 % of current national funding for gas efficiency programs, Tier II consists of another 15 states where 2010 spending on gas efficiency programs exceeded $0.50 per capita, and Tier III consists of the remaining 23 states (see Technical Appendix 1 for the set of states included within each tier).
Scenario assumptions for gas energy efficiency projections
Representative assumptions (specific assumptions vary by state)
Tier I states
Assume new furnace equipment standards and moderate gas prices cause a reduction in residential program spending to 25 % of the level from the most recent gas DSM plan, and to 80 % for commercial & industrial programs. No change in low-income program spending.
Assume new furnace equipment standards and moderate gas prices cause a reduction in residential program spending to 50 % of the level from the most recent gas DSM plan, but a slight increase in C&I program spending. No change in low-income program spending.
States reach stipulated benchmarks for gas program savings ranging from 1.0 to 1.5 % of total gas distribution utility sales.
Tier II states
Regional benchmark (average) based on low, medium, and high scenarios in Tier I
Tier III states
Spending remains at 2010 levels in absolute nominal dollar terms
Spending remains at 2010 levels as a percentage of gas distribution utility revenues
Spending percentage increases above current levels by 0.25 % of gas distribution utility revenues
The 15 Tier II states have relatively aggressive spending levels on a per capita basis, but small populations and therefore small spending levels in absolute terms. Thus, for simplicity, the spending projections for these states were developed based on regional benchmark trajectories that were developed from the projections for Tier I states in the corresponding region. These regional benchmark trajectories were developed by averaging the change in spending as a percentage of gas distribution utility revenues per year by region for the Tier I states in each census region. Those growth curves were then applied to the 2010 spending for each Tier II state. As an example, in the medium case, spending for the three Tier I states in the Northeast (MA, NY, and NJ) is projected to increase by, on average, 0.6 % of revenues; thus, the same 0.6 % increase in spending as a percent of revenues was stipulated for the Tier II northeastern states in the medium case. For further details, please refer to Technical Appendix 1.
For the remaining 23 Tier III states that currently have little or no customer-funded gas program activity, we assumed that future gas efficiency spending will, in the low case, remain at 2010 levels in absolute nominal dollar terms (thus declining as a percentage of gas distribution utility revenues, as revenues grow). In the medium case, we assume that program administrators maintain gas efficiency spending at their present level, in terms of the percentage of utility revenues. The high case posits that program administrators will increase program spending to approximately 0.25 % of revenues above 2010 levels by 2025.
In this section, we present our projections of spending on utility customer-funded energy efficiency programs through 2025. We first present total projected spending for electric and gas efficiency programs, combined, before turning to the projections for each fuel individually. We also present projections of electric energy savings associated with the three spending trajectories for electric efficiency programs and consider the potential significance of these savings projections in relation to current expectations about future load growth in the electric sector.16 The results presented throughout this section focus primarily on national and regional trends; the corresponding state-level projections are provided in Technical Appendix 2.
Combined electric and gas energy efficiency program spending projections
As discussed further in the following sections, projected growth rates for electric efficiency program spending are somewhat higher than for gas program spending in both the low and medium cases, with projected electric program spending growth of 2.3 and 4.9 % per year in the low and medium cases, versus less than 1.1 and 3.8 % per year for gas programs. In the high case, however, gas efficiency spending grows faster than electric spending (9.7 vs. 7.8 %). These differing trends reflect, in large part, the broader base of underlying policy support for, and historical experience with, electric efficiency programs, leading to stronger growth in the low and medium cases for electric programs, while leaving a large upside potential for growth in gas program spending under the high-case conditions.
Electric energy efficiency program spending projections
Projected electric energy efficiency spending
Projected spending ($B, nominal)
Projected spending (% of revenues)
Average annual spending growth (%)
Importantly, the projected growth in electric program spending across all cases does not occur smoothly over the forecast period, but rather is “front-loaded,” with much faster growth projected through 2015 (Table 5). In the medium case, for example, spending grows by 11 % per year through 2015 but by only 2 % per year from 2020 to 2025. This dynamic is partly due to the fact that, in many states, recent multi-year DSM plans entail significant spending increases over the next several years, but no longer-term targets or resource planning process currently exists to guide program activity beyond the time horizon of the DSM plan. The front-loaded spending projections also reflect the trajectory of EERS schedules, which typically reach their terminal targets by 2020 or sooner. From 2020 onward, we assume that spending growth in many states tapers off and grows roughly in proportion with projected revenues, reflecting both a lack of strong policy drivers for continued spending growth after 2020, as well as the assumption that savings potential within the 2020–2025 period will be diminished due to the success of programs implemented over the prior decade and tightening federal efficiency standards.
In the West and Northeast—the traditional bastions of energy efficiency activity—electric program spending is also projected to increase in the medium case, though by lesser amounts than the other two regions, reflecting the more mature state of those markets. In the Northeast, efficiency program spending is projected to increase under all three scenarios, where differences in spending levels between the medium and high cases are largely driven by assumptions about how utility program administrators and state regulators translate statutes requiring acquisition of all cost-effective efficiency into multi-year savings goals. For the West, the regional trends are dominated by California, where electric program spending in both the medium and low cases is projected to decline over the long term, as saturation within key end-use markets occurs and as the state leans more heavily on other energy efficiency policies (Navigant Consulting Inc. 2012). In the medium case, those declines are offset by spending growth in other western states, leading to net spending growth for the region as a whole, while in the low case, total electric program spending in the West is projected to decline slightly.
Electric energy efficiency program savings projections
In 2010, electric energy efficiency programs in the USA achieved incremental energy savings of 18.4 TWh, equivalent to 0.49 % of electric utility retail sales nationally (Foster et al. 2012).17 In comparison, leading states, where program administrators typically have a decade or more of experience in delivering energy efficiency programs, have achieved annual savings of more than 1.0 % of retail sales (e.g., CA, CT, MA, OR, VT, NV, HI, RI, and MN), and a sizeable contingent of other states has consistently achieved savings in excess of 0.50 % of retail sales.
Projected incremental annual electricity savings from utility customer-funded programs (TWh)
To place these savings projections in perspective, the Energy Information Administration (EIA)’s most recent reference case forecast (EIA 2012) projects that total U.S. retail electricity sales will grow at a compound annual growth rate (CAGR) of 0.58 % over the 2010 to 2025 period, which is substantially lower than the average U.S. load growth of 1.6 % per year over the past two decades. The EIA’s modeling framework does not explicitly account for the impacts of future utility customer-supported efficiency programs; however, the model implicitly operates under the assumption that historical trends in utility customer-funded efficiency programs will continue over the forecast period. For the period 2000 to 2010, we estimate that utility customer-funded energy efficiency programs nationally achieved incremental savings of roughly 0.18 % per year, on average.20 Thus, if one were to assume that the EIA reference case forecast implicitly assumes that savings from customer-funded electric efficiency programs continue to accrue at this historic rate, then a hypothetical reference case forecast with no future customer-funded energy efficiency activity would correspond to a CAGR of 0.76 % (i.e., 0.58 % plus 0.18 %).
Our medium case projection corresponds to average annual incremental savings of 0.72 % of retail sales per year between 2010 and 2025. This, in turn, implies that if electric utility customer-funded efficiency programs achieve savings at the level projected under our medium case, they would reduce growth in U.S. retail electricity sales to just 0.04 % per year through 2025 (i.e., 0.76 % annual growth with no future efficiency program activity minus projected annual incremental savings of 0.72 % of retail sales per year under the median case), offsetting almost all projected load growth under EIA’s 2012 reference case forecast.21 Following the same logic, our low case and high case savings projections would offset roughly 70 and 120 % of load growth, respectively, yielding average annual growth rates for retail electricity sales of 0.21 and −0.18 % from 2010 to 2025. To be sure, these benchmarks should be considered no more than a “back-of-the-envelope” estimate of the impact of projected customer-funded efficiency program savings on load growth in the USA. Nevertheless, they suggest that rising savings levels, in combination with modest underlying drivers for load growth, can potentially lead to flat, or even negative, load growth over the next 10 to 15 years.
Gas energy efficiency program spending projections
Discussion of key issues and uncertainties
The preceding set of projections suggest a wide range of potential trajectories for utility customer-funded energy efficiency program spending and savings in the USA—even without considering the possibility of fundamentally new policy developments. In this section, we identify some of the significant issues and uncertainties that may influence the spending course and impact of these programs over the next 10 to 15 years and which we attempted to account for—either directly or indirectly—within the projections. These interrelated issues and uncertainties include both external factors, such as the broader policy and market context within which utility customer-funded programs operate, and internal factors related to the implementation and regulatory oversight of these programs.
Broader market and policy context
Utility customer-funded energy efficiency programs and their enabling policies function within a broader context, influenced by a variety of market forces and conditions, as well as by interactions with other policies. We briefly highlight four key elements of this broader market and policy context that may be particularly critical to the future trajectory of customer-funded efficiency programs: the state of the economy, natural gas prices, federal minimum efficiency standards, and environmental regulations affecting the electric power sector.22
The timing and extent of the economic recovery may complicate and restrain efforts to scale-up energy efficiency spending and savings over the near to medium term, for several reasons. First, utility customer-funded energy efficiency programs typically require customers to pay a portion of the capital outlay for energy efficiency measures; as households and businesses struggle to manage their day-to-day expenses, and as declining home values reduce the equity available for financing efficiency improvements, many customers may be reluctant make new investments, even those with short payback periods. As a result, program participation may be suppressed, or program costs may rise if program administrators are required to increase financial incentives or expend greater sums on marketing efforts. Second, a stagnant economy is likely to reduce the rate of stock turnover and new housing starts, thereby reducing the amount of energy savings that could be captured through utility customer-funded programs targeting these market opportunities. Third, a slow economy may indirectly constrain energy efficiency program efforts in at least three ways: heightened sensitivity to potential near-term rate impacts associated with efficiency program spending,23 increased risk that policymakers will re-direct dedicated funding for energy efficiency to shore-up state budgets24 or other non-efficiency purposes, and slowed load growth, thereby reducing the avoided capacity costs and cost-effectiveness of energy efficiency programs.
Moderate natural gas prices
As of April 2012, natural gas was trading at wellhead prices of less than $2 per million British thermal units, the lowest level in 10 years and nearing a record low. Although natural gas prices are projected to rise over the next 20 years (EIA 2012), they are nevertheless expected to remain lower, in real terms, than the prices that characterized most of the past decade, when most state energy savings targets were set.25 For electric and gas energy efficiency programs, lower gas prices translate into reduced program benefits, which in turn constrains total efficiency spending and flexibility in program design as benefit–cost ratios decrease. More aggressive efficiency portfolios and comprehensive, multi-measure programs may be especially at risk because costlier measures will result in longer payback periods for customers and will not be as cost-effective from a total resource cost perspective. The effects of moderate gas prices will be especially pronounced for natural gas efficiency programs because lower gas commodity costs mean lower avoided energy costs to gas utilities, which affects program cost-effectiveness. Lower gas prices also mean that customers will have incentive to increase consumption or convert to gas heating from other fuels and will have less direct financial incentive to invest in energy efficiency.
State and federal end-use codes and standards
In recent years, state adoptions of building energy codes have increased, and federal minimum efficiency standards for appliances and end-use equipment have been tightened. These policies affect utility customer-funded programs by essentially raising the baseline against which savings are measured, thereby influencing both the size of the remaining potential that can be harvested through those programs and the mix of technologies targeted. Two specific federal efficiency standards that are planned to go into effect over the near term—for lighting in 2012 to 2014, then again in 2020, and for non-weatherized natural gas furnaces in 2013—may have potentially significant impacts on customer-funded efficiency programs. The impact of the federal lighting standards is somewhat less certain because program administrators have other lighting technologies that are likely to remain cost-effective after the standards come into effect. Gas program administrators, however, may have fewer options. Starting in 2013, the new furnace standards would raise the minimum heat-to-fuel efficiency of furnaces from 78 to 90 % AFUE26 in northern states (generally the states with the nation’s most substantial spending and savings targets). Programs can continue to provide incentives for higher efficiency gas furnaces, but with a technological efficiency limit of about 98 % AFUE, the incremental savings will be lower, and residential gas furnace programs are therefore less likely to continue as the mainstay of gas efficiency program portfolios.
Proposed or final air emissions regulations that are being considered or adopted by state and federal environmental agencies27—in combination with low-priced, abundant gas—have become important drivers for utility customer-funded energy efficiency programs, as part of utilities’ multi-faceted strategies for managing the retirement of older coal-fired generators.28 For example, many utility resource plans have discussed the potential role of demand-side resources as part of a strategy for complying with emissions requirements (e.g., Tennessee Valley Authority), as a prerequisite for utility customer funding of low carbon replacement generation (American Electric Power in West Virginia, Florida Power & Light in Florida), or as a means of deferring retirement and replacement decisions (Duke Energy Carolinas). The ultimate import of these regulations for future energy efficiency program budgets, however, depends on several factors. These factors include: the timing and stringency of the final rules, the price of natural gas (as gas-fired generation is expected to offset the majority of the retired coal-fired generation), the capital cost profile of clean energy generation alternatives (e.g., renewable energy, nuclear power, coal with carbon capture and sequestration), the regulatory and business models in place that govern the balance and relative attractiveness of supply- and demand-side investments, and the degree to which utilities and utility regulators integrate state and tribal Clean Air Act implementation plans with utility resource plans.
Energy efficiency program implementation and regulatory oversight
There are also a variety of other critical issues and uncertainties specific to the regulatory and administrative institutions within which utility customer-funded efficiency programs operate and that may strongly influence the spending and savings trajectories of those programs. Here, we highlight several: general aversion to rate impacts, challenges associated with developing innovative program designs to reach deeper and broader savings, and the limited ability in some states to extend gas efficiency programs to transportation gas customers.
Aversion to rate impacts
In most states, utilities typically expense program costs for energy efficiency as they are incurred. As a result, energy efficiency program cost recovery is relatively front-loaded compared to cost recovery for most utility supply-side resource alternatives. As a result, the rate impacts from energy efficiency tend to occur sooner (even if the rate impacts are less over the long term, and even if average utility bills are reduced compared to supply-side alternatives). The short-term rate impacts associated with attaining very aggressive levels of savings (or even relatively modest levels of savings in states that are higher than has historically occurred) could pose a political challenge for state regulators, particularly in states that have seen significant rate hikes in recent years or whose rates are well above national averages. Across all states, these challenges are further heightened during periods of economic hardship. Concerns about rate impacts from energy efficiency programs have been institutionalized in a number of states, either through explicit caps on spending or rate impacts, or by the application of the ratepayer impact measure (RIM) test.29 Meeting aggressive EERS targets in some states will likely require exceeding these caps or otherwise justifying rate increases, which may be feasible only in a robust, growing economy.
Developing innovative program designs to reach deeper and broader savings
A number of states have established aggressive energy efficiency savings goals for future years that are well beyond current experience and practice in most leading states (e.g., annual incremental electric savings on the order of 1.5 to 2 % or more of retail sales). The challenge for these program administrators will be to design and implement programs that can achieve both deeper savings, on average, at customer facilities and have a broader reach in terms of market penetration over a sustained period of time. Service providers will have to achieve savings levels of 25–40 % of existing usage at customer facilities compared to current practice in utility customer-funded programs, which is typically in the 5–20 % range. Achieving higher market penetration rates will require programs to target and reach traditionally underserved markets (e.g., small commercial, multi-family, rental housing, moderate income households, non-owner occupied commercial facilities) in far greater numbers than current practice (MEEAC 2009). We are also likely to see increased attention to integrated delivery of electric and gas efficiency programs as well as coordinated delivery of energy efficiency, on-site renewable and combined heat and power, in order to reduce transaction costs and provide customers with tailored, customized service offerings.
Extending programs to transportation gas customers
In a significant number of states, energy savings in the large commercial and industrial markets are, in effect, beyond the reach of program administrators. This is especially true for gas efficiency programs as large commercial and industrial customers often purchase natural gas on the competitive market through alternative retailers, and may not pay into or be able to participate in gas utility customer-funded energy efficiency programs.30 This “transportation gas” accounts for 46 % of total U.S. gas sales and 79 % of all commercial and industrial sales. The ability for many states to significantly increase gas efficiency program savings and spending may therefore hinge, to a large degree, on whether mechanisms can be developed (e.g., non-bypassable charges for program funding) to bring these customers and savings opportunities into the program fold.
Energy efficiency programs funded by utility customers are poised for dramatic growth over the course of the next 10 to 15 years, especially in the Midwest and South—with a contingent of populous Midwest states ramping up to meet statutory EERS targets, and in the South, the expectation that a collection of relatively modest EERS policies and nascent IRP/DSM planning processes in states with a large base of energy consumption will push spending upward from currently low levels. As a result, program spending is expected to become more evenly distributed nationwide by 2025.
Program spending is projected to roughly double to $9.5 billion in 2025 and could reach $15.6 billion under aggressive assumptions about the policy support, implementation, and effectiveness of current policies. Program administrators in many states are projected to achieve annual electricity savings of between 1.5 and 2 %, surpassing the achievements of most leading states today.
Given forecasts for a slow economy recovery and modest load growth, the projected growth in electricity program spending and savings under our medium case scenario would offset most aggregate annual U.S. load growth through 2025, based on the load forecast in EIA’s most recent reference case (and given specified assumptions about the extent to which EIA’s forecast captures the impact of future efficiency programs).
However, program administrators and state regulators face emerging challenges and uncertainties. The combined effects of economic torpor, moderate gas prices, and tightening energy codes and minimum efficiency standards pose challenges for continued growth in electric and, especially, gas efficiency programs. The degree to which leading states and a new vanguard of fast-rising states can overcome these challenges and offset reduced efforts elsewhere is likely to govern the longer term path for national-level spending and savings.
The American Recovery and Reinvestment Act (ARRA) provided a massive but temporary infusion of federal funding for energy efficiency (∼$15–20B in programs administered by federal, state, and local governments to be spent over 3 years) (Goldman et al. 2011).
Energy efficiency programs administered by U.S. gas distribution utilities have also increased over time but are much smaller in size than electric efficiency programs (York et al. 2012).
By virtue of limiting the analysis to current energy efficiency policies, we do not consider the potential impact of major new federal (or state) policy initiatives (e.g., a national energy efficiency resource standard, clean energy standard, or carbon policy) that could result in customer-funded energy efficiency program spending and savings that exceed the values in our High Case.
In this study, we define Energy Efficiency Resource or Portfolio Standards as requirements under statute or regulatory order that some or all utilities within a state (e.g., all utilities or investor-owned utilities only) achieve specified minimum savings levels over a period greater than 3 years. States with shorter term DSM plans (i.e., 1 to 3 years) and/or multi-year efficiency budgets approved by state regulators are separately listed. Note that other entities (e.g., ACEEE) that track the status of energy efficiency policies in various states may use slightly different criteria for defining an EERS than LBNL; thus, their tallies of the number of states with such policies may differ.
In Arkansas, the process began with a collaborative among regulators, utilities, and other stakeholders, then proceeded to “quick start” programs designed to test the viability of utility customer-funded programs in that jurisdiction and begin building program infrastructure. In the final step, regulators set modest but increasing savings targets.
For example, Duke Energy Carolinas and Progress Energy Carolinas are subject to an RPS in North Carolina in which energy efficiency is an eligible resource, and both submitted a pro rata version of the same efficiency plan from North Carolina for the rest of their service territory in South Carolina. Likewise, West Virginia’s requirement that an American Electric Power subsidiary initiate efficiency programs resulted in submission of similar program plans in neighboring Virginia.
The Tennessee Valley Authority (TVA) is the largest U.S. public power company and serves 155 distributors and 57 industrial customers in TN, KY, AL, MS, GA, NC, and VA.
Electric utility expenditures on load management programs in 2010 represented an additional $0.9 billion (CEE 2012).
Metrics based on total budget for energy efficiency tend to favor states with large populations. It is important to note that program administrators in several small states (e.g., VT, RI, and IA) have significant energy efficiency budgets, if metrics are based on efficiency spending per capita. In the USA, the ten leading states spend more than $25 per capita on utility customer-funded electric efficiency programs, while the average spending on these programs among the 50 states is about $12 per capita.
See approach section on modeling of gas programs for more details.
On a national basis, electric energy efficiency spending in 2010 was allocated among market sectors as follows: commercial and industrial (47 %), residential (28 %), low-income residential (8 %), and other programs or expenditure categories not directly attributable to a sector (16 %).
In the context of this report, “spending” refers to the flow of money from the energy efficiency program administrator into the market, including all program administration costs but excluding performance incentives. To the extent possible, electric spending projections are intended to reflect “gross” savings, prior to accounting for free riders or free drivers. This approach was taken in order to abstract from potential inconsistencies across states in methods for estimating net-to-gross ratios. However, the underlying data used to derive the cost of savings for some states were not explicit about whether savings are reported in “net” or “gross” terms; thus, some ambiguity exists in whether the spending projections for a number of states reflect net or gross savings. Gas efficiency program savings projections were not included for several reasons (e.g., relative paucity of mature, multi-year gas efficiency programs from which to draw reliable data).
A comprehensive explanation of the analytical methodology may be found in a technical appendix posted at http://emp.lbl.gov/publications/future-utility-customer-funded-energy-efficiency-programs-united-states-projected-spend
These seven uncommitted states include: AK, KS, LA, ND, NE, SD, and WV.
We do not present projections of natural gas program savings as insufficient data exist to link the projected spending amounts to specific savings trajectories.
Note that energy savings number cited here represents first-year savings from programs implemented in 2009, and should not be confused or compared with other estimates (e.g., CEE 2012) that refer to the combined impact in any given year from both programs implemented in that year and from programs implemented in prior years.
To the extent possible, spending projections are intended to reflect “gross” savings (i.e., prior to accounting for free-riders or spillover effects). This approach was taken in order to abstract from potential inconsistencies across states in methods for estimating net-to-gross ratios.
For many states, our analysis assumes constant savings percentages from 2020 to 2025; those assumptions are reflected in the national totals in Fig. 7, which similarly shows a flat or slight decline in savings percentages from 2020 to 2025.
EIA’s National Energy Modeling System is calibrated to historical data on end-use stock efficiency and shipments, and the customer adoption simulation assumes, in essence, that consumers will continue purchasing equipment that exceeds minimum efficiency standards to the same extent as has historically occurred. This estimate of incremental savings from efficiency programs is based on ACEEE data for national electric efficiency program savings for 2006–2010, and savings for 2000–2005 are estimated based electric efficiency program spending for those years.
One must interpret this finding with a certain degree of caution given that: (a) EIA’s 2012 reference case load forecast projects much slower growth in electricity demand and in economic activity than has historically occurred, and (b) uncertainty regarding the precise extent to which EIA’s load forecast accounts for the impacts of future electric utility customer-funded efficiency programs. Our results suggest that additional analysis of the amount of future energy efficiency program savings that is implicit in EIA’s reference case forecast and more consistent accounting of free rider and spillover effects is warranted, although beyond the scope of this study.
Other aspects of the broader market and policy context that may impact future customer-funded energy efficiency program activity include the development of alternative utility business models, increasing capital costs for conventional generation technologies, greenhouse gas mitigation policies, and the lasting effects of ARRA-funding on energy efficiency program delivery infrastructure and energy efficiency potential.
Lawmakers in Wisconsin and regulators in Florida, for example, have both cited rate impacts in repealing or lowering energy savings targets.
Actual diversions of SBC funds to state general funds have been considered by state legislators in a number of states and have actually occurred in several states. For example, nearly a third of program revenues in Connecticut were redirected to the state general fund. New Jersey’s governor diverted $279 million in utility customer funds to close 2012 and 2013 state budget gaps. California lawmakers considered diverting $161 million in gas SBC funds to the state general fund, but a state court denied the transfer.
The trajectory for gas prices, and the implications for spending and performance of gas energy efficiency programs, could change in response to, for example, tighter regulation of hydraulic fracturing, an acceleration in the expected increase of demand among gas-fired generators, or large-scale, near-term exports of liquefied natural gas.
Annual fuel use efficiency (AFUE) is an equipment rating intended to measure the season-long, average efficiency of equipment as a ratio of thermal energy output to fuel energy input. An AFUE of 78 %, the current U.S. standard for furnaces, represents an average of 78 Btus of heat for every 100 Btus of energy in the combusted fuel.
Efforts to limit these emissions span multiple sets of regulations—for air toxics, for nitrogen and sulfur oxides, for greenhouse gases, for managing coal ash, and for limiting once-through cooling for generators—and each of these regulations has its own timeline and likelihood of coming into effect.
Coal-fired generators are the nation’s largest single source of acid gases, carbon dioxide, and air toxics such as mercury. The oldest coal-fired generators in the USA, generally those of 1960s vintage or earlier, would be most affected by these environmental regulations. See CRS (2011), Brattle Group (2010), and Bipartisan Policy Commission (2011) for a more detailed discussion of these regulations, their timing, and the projected impacts on the electric power industry.
For example, Michigan and Illinois have spending caps in their EERS legislation. In Wisconsin, lawmakers rescinded regulatory discretion over program spending and capped spending at about half the levels anticipated to meet original savings targets. In Florida, the PSC continues to rely heavily on the RIM test to screen energy efficiency programs; the RIM test highlights potential rate impacts on non-participants rather than reductions in average customer bills from cost-effective efficiency investments.
Related, large electricity customers in some utility service areas may either “opt out” of paying charges for energy efficiency programs or direct most or all of their share of those charges into their own, “self-direct” energy efficiency investments.
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