Clean Air/Emissions (RSS)

Wisconsin Power & Light Offers Emission-Saving Goodies to Make New Coal Plant Proposal Palatable

In an effort to counter opponents of its proposal to expand an existing coal-fired generating station by 300 MW, Wisconsin Power & Light (WP&L) has offered to take several steps to offset the increased greenhouse-gas emissions that would result from the expanded plant's operation.  In a draft environmental impact statement, the Wisconsin Public Service Commission criticized WP&L's proposed use of a circulating, fluidized bed (CFB) boiler, which results in higher CO2 emission.  In response, rather than abandon CFB, WP&L has offered to retire the oldest coal-fired plant in its fleet, develop an additional 200 MW of wind power above the 300 MW it has already pledged to develop in the next several years, increase the amount of biomass co-firing planned for the new unit, and increase energy efficiency and conservation efforts.  WP&L's estimated cost for these proposed efforts are $500-$550 million. 

The approach taken by WP&L proved successful for another Alliant Energy Corp. subsidiary.  Interstate Power & Light offered to the Iowa Public Utility Board a package of actions, including retiring older plants, building more wind power and increasing biomass co-firing in order to win the Board’s approval of a new coal-fired plant.  More quid-pro-quos of this sort can be expected.  Even as federal greenhouse gas legislation recently failed to overcome a threatened filibuster, its eventual passage appears probable and will impact state regulatory decision making.
posted Wednesday, June 25, 2008 9:56 AM by Andrea Kells

DC Circuit Orders Immediate Tightening of Mercury Control Rules

On March 21, a three-judge panel of the US Court of Appeals for the District of Columbia Circuit made clear that its February 8, 2008 order mandating a return to tighter mercury control rules on coal-fired power plants must go into effect immediately.  The court's February order threw out the Bush Administration's Clean Air Mercury Rule (CAMR), which was implemented in 2005 and established a cap-and-trade program for mercury emissions from coal- and oil-fired power plants, and directed a return to the more stringent standards enacted in 2000 under the Clinton Administration.  The court's most recent ruling requires the Environmental Protection Agency (EPA) to begin implementing the tighter rules immediately, instead of allowing time for the EPA and others to request rehearing of the court's February order.

In its February order, the court rejected the EPA's CAMR standards as violating the Clean Air Act.  The CAMR standards required coal- and oil-fired plants to reduce mercury emissions by 70% by 2018, and permitted utilities to trade mercury emissions to allow them to reduce compliance costs.  The CAMR standards also reversed the 2000 mercury standards, which had required mercury emissions to be regulated under a maximum achievable control technology (MACT) standard.  The MACT standard that will now take effect again requires proposed power plants to adopt emissions controls in use at the best controlled similar pollution source, which will likely require power plants to remove an estimated 85% to 90% of the mercury from their emissions. 

The court's ruling will have an immediate impact on coal-fired plants that are currently in the planning and permitting stages, as these plants will have to revise their plans and permit applications in order to remove higher amounts of mercury.  However, the EPA and several utilities that supported it have indicated they plan to seek rehearing of the court's February order, and thus the ruling could be modified or reversed following en banc review.  In the meantime, the court's recent order requires the EPA to begin tightening its controls immediately.

posted Tuesday, March 25, 2008 4:41 PM by Tracy Davis

Department of Energy Pulls Plug on FutureGen Program

The Department of Energy has cancelled the FutureGen project in which the DOE and a coalition of energy industry companies would have constructed a nearly emissions-free, coal-fired generator.  The futuristic project involved carbon capture and sequestration (CCS) underground as part of an integrated gasification combined cycle 275 MW plant producing both electric power and hydrogen.  The cancellation comes as a particularly hard blow to the people in Mattoon, Illinois who had prevailed in an intense competition with other U.S. locales to host the project.   

FutureGen had been touted as a model plant for devising a way to generate power from coal, while minimizing the release of carbon dioxide into the atmosphere.  This approach to battling climate change is important to countries such as U.S., China, and India that have both vast coal reserves and great energy needs.  But the DOE cited the increased costs of the project ― recent estimates had doubled the costs to $1.8 billion ― as a key reason for pulling the plug on the nascent project.

In lieu of FutureGen, the DOE has opted for what may be a more practical approach.  Rather than sponsor one, very expensive project, the Department explained that it would invest in development and application of CCS technologies that could be applied in numerous power plants that would each be funded by its respective developers.  The DOE has issued a request for information asking for industry input on the costs and feasibility of building clean coal facilities that meet the goals of FutureGen.  Comments are due by March 3.  Following receipt of comments, the DOE plans to issue competitive solicitations for federal funding to equip IGCC plants with CCS technology.  If the technology can be implemented, it could be part of new coal plants coming on-line by approximately 2015. 

posted Tuesday, February 05, 2008 12:22 PM by Gunnar Birgisson

North Carolina Brings Southeast to RPS Table; Illinois & Delaware Expand RPS Laws

Various states around the country have recently created or expanded their renewable portfolio standard (RPS) requirements.  The combination of traditional RPS requirements with complimentary initiatives, including cost recovery incentives, energy efficiency directives and voluntary green power programs, characterize these recent additions to the nation's RPS goals.

With its recent enactment of a Renewable Energy and Energy Efficiency Portfolio Standard (REPS), North Carolina has become the first southeastern state to join the ranks of RPS states.  The REPS will be phased in beginning in 2012; it requires that by 2021 all investor-owned utilities within the state meet 12.5% of their 2020 energy needs from renewable energy resources or energy efficiency measures.  A reduced requirement of 10% applies to rural electric cooperatives and municipal electric suppliers.  Until 2018, up to 25% of the requirement may be met through energy efficiency efforts, including combined heat-and-power systems powered by non-renewable fuels.  After 2018, 40% of the standard may be met by energy efficiency strategies.  Other noteworthy facets of the new law are its provisions (1) permitting utilities to recover certain incremental costs incurred to comply with the REPS, to fund renewable energy or energy efficiency research, or comply with any future federal RPS mandate, (2) requiring electric power suppliers to implement demand-side management and energy efficiency measures and providing for cover recovery for those measures, and (3) extending rate recovery to construct costs associated with out-of-state generating facilities.   

Building on its previous voluntary renewable portfolio goal of 8% by 2013, Illinois recently enacted a new law that creates the Illinois Power Agency (IPA) and charges it with developing electricity procurement plans for state utilities serving over 100,000 customers and then competitively procuring energy according to those plans.  The IPA's procurement activities must also meet an expanded and now-mandatory RPS of 25% by 2025, beginning in 2008 with a 2% requirement.  A minimum of 75% of the renewable energy must be produced from wind.  The new law also requires that utilities establish annual energy savings goals in order to meet a percentage of their energy delivery requirements through efficiency efforts. 

In another expansion of an existing RPS, Delaware has increased its requirement, previously at 10% by 2019, to 20%, 2 percent of which must be obtained from solar photovoltaics.  The expanded RPS applies to investor owned utilities, municipal utilities and rural electric cooperatives, though the municipals and rural coops were permitted to opt out of the RPS requirements upon establishment of a voluntary green power program and creation of a green energy fund.
posted Friday, September 07, 2007 9:43 AM by Andrea Kells

CPUC to Consider Innovative Energy Efficiency Incentives for State's IOUs

The California Public Utilities Commission (CPUC) will soon consider an innovative incentive program to encourage the state's investor-owned utilities (IOU) to meet energy savings goals.  Based on an August 9 proposed decision by CPUC Commissioner Dian Gruenich and Administrative Law Judge Meg Gottstein, the proposal would pay the IOUs -- include Pacific Gas & Electric Co., San Diego Gas & Electric Co., Southern California Edison Co., and Southern California Gas Co. -- up to $323 million over three years if they exceed the base targets.  If utilities satisfy these goals, the plan would purportedly save California ratepayers $2.4 billion and cut about 3.4 million tons of carbon dioxide emissions in 2008.  Conversely, if the utilities fail to meet the base targets, the plan would impose monetary penalties on them.  The proposal caps both potential earnings and losses for shareholders at $500 million.

Commissioner Gruenich, the plan's chief proponent, argued that the proposal would provide "both a meaningful level of shareholder earnings and an estimated return of over 100 percent on ratepayers' investments in energy efficiency as the utilities reach toward and exceed our 2006-2008 energy savings goals."  The proposed decision is on the CPUC's agenda for its September 20 meeting.

posted Tuesday, September 04, 2007 9:04 AM by Tracy Davis

Western Climate Initiative Seeks 15 Percent Reduction in Greenhouse Gas Emissions

Achieving one of the goals set for itself at its inception, the Western Climate Initiative (WCI) has pledged to reduce aggregate regional greenhouse gas emissions to 15 percent below 2005 levels by 2020.   

Initially composed of Washington, Oregon, Arizona, New Mexico and California, the WCI was established in February 2007 with the goal of collaborating on climate action initiatives across the Western U.S., Canada and Mexico.  Since that time, Utah and the Canadian provinces of British Columbia and Manitoba have joined.  Several other states and provinces have signed on as "observers" to the WCI, including Sonora, Mexico; Wyoming; Colorado; Kansas; Nevada; and Ontario and Quebec, Canada. 

According to the Statement of Regional Goal that WCI issued last week, the regional 15 percent goal reflects the cumulative emission reduction goals of the "partner" states and provinces, and does not replace those partners' existing reduction goals, some of which — such as California's — are more aggressive than the WCI goal.   

The regional plan calls for each WCI partner to update the others on its emissions inventories every two years.  It also details the criteria for new partners to join the group, which turn on whether the new entrant is undertaking efforts comparable to the current partners' to address climate change.
posted Wednesday, August 29, 2007 4:05 PM by Andrea Kells

House Passes Energy Bill with 15% RPS Requirement, Other Clean Energy Initiatives; House and Senate Must Now Reconcile Vastly Different Legislation

On the heels of a Senate bill passed in June, the House of Representatives on August 4 passed a comprehensive energy bill by a vote of 241 to 172.  The House bill is drastically different from the Senate's energy legislation, and it appears the House and Senate face an arduous conference to reconcile the two versions, which contain drastically different approaches to energy policy.

In summary, the House bill:

  • Incorporates a 15% renewable portfolio standard (RPS), requiring utilities to produce at least 15% of their electricity through the use of renewable energy resources (e.g., wind or solar power) by 2020;
  • Sets a goal of eliminating greenhouse gas emissions by federal agencies by 2050;
  • Establishes new efficiency standards for appliances, lighting and buildings, while promoting new technologies for transmitting and delivering energy to create a "smart grid;"
  • Authorizes billions of dollars for research into sustainable energy sources and alternative fuels, including research into carbon dioxide sequestration efforts;
  • Resolves the sticky issue of numerous "faulty" leases in the Gulf of Mexico that arose when the Department of the Interior erroneously executed leases with several oil and gas companies that provided the companies with excessive royalties, by requiring the oil and gas companies to either renegotiate the leases or pay a conservation fee before bidding on future leases; and
  • Promotes international energy-efficiency standards and U.S. involvement in other international partnerships to address energy issues and climate change.

The House also passed a companion package of changes to the tax code, by a vote of 221-189.  The tax bill offers various incentives to encourage the use and production of renewable energy and energy conservation, including new tax credit bonds to encourage energy efficiency in residential property and more production of clean energy, and $3.6 billion in bonds for state and local governments to fund energy conservation efforts.  The bill pays for these tax incentives by repealing approximately $16 billion worth of tax breaks for oil and gas companies.

There are several notable absences in the House's bill.  For instance, the bill does not revoke or condition the backup transmission siting authority given to FERC in 2005's Energy Policy Act in so-called "national interest electric transmission corridors," a provision that has raised significant concern in states with controversial transmission projects, like New York and Virginia. Similarly, the House bill does not set new corporate average fuel economy (CAFE) standards for cars and trucks, nor does it provide any support for coal-to-liquid production, both of which were contained in the Senate's energy bill.

It may prove a substantial battle to reconcile the House's and Senate's legislation.  While both bills included some of the same provisions, including requirements for research and development of carbon sequestration, biomass resources, and cellulosic ethanol and biodiesel, the two versions appear to be quite far apart on several major policy issues.  Key differences include:

  • the House's inclusion of an RPS, which the Senate bill did not contain;
  • the House bill's expanded energy efficiency provisions, which are more expansive than the Senate's version, which only included new standards for appliances and lighting;
  • the House tax bill's rescission of approximately $16 billion in tax breaks for oil and gas companies, which the Senate bill does not contain;
  • the Senate's inclusion of increased CAFE standards, requiring 35 mpg by 2020 for cars, SUVs, and small trucks, which the House bill omitted;
  • the Senate bill's ethanol mandates, which require that the use of ethanol increase by sevenfold by 2022 and that 85% of cars manufactured by 2015 be capable of running on E-85 fuel (a blend of 85% ethanol and 15% gasoline); the House's bill did not contain such ethanol provisions; and
  • the Senate bill's provision making it unlawful to charge an "unconscionably excessive price for oil products, including gasoline, which the House bill does not include.

The House and Senate will likely convene a conference committee this fall to attempt to iron out these differences.  Even if able to come to a compromise, White House approval is not assured.  Shortly after the passage of the House bill, the White House indicated its opposition to many of the bill's major provisions, stating that it would not "deliver American consumers or businesses more energy security, but rather would lead to less domestic oil and gas production, higher energy costs, and higher taxes." 

posted Monday, August 13, 2007 5:20 PM by Tracy Davis

States Pursue Cleaner, Sustainable Energy, but not Too Quickly

While climate change legislative proposals and potential energy legislation continue  to muddle in the halls of Congress, individual states keep on creating their own requirements for checking green-house gas emissions and requiring greater use of renewable energy within their borders.  Whether this will lead to a mosaic of disparate standards and obligations or eventual standardization across state lines remains to be seen.

Despite relatively limited renewable energy production potential and a sharply growing population in Florida, Governor Charlie Crist (R) recently issued several executive orders intended to reduce greenhouse gas emissions and increase renewable energy use.  The orders direct the state’s public service commission to initiate a rulemaking intended to achieve a renewable portfolio standard (RPS) of 20%; call for capping utility greenhouse gas emissions at their 2000 level by 2017, reducing them to their 1990 level by 2025, and to 20% of their 1990 level by 2050; and implement other measures such as new interconnection standards, net metering, and requiring state agencies to take additional energy efficiency measures.

Hawaii already has an RPS, and its legislature recently added climate change legislation.  Its objective is to reduce the level of greenhouse gas emissions in the state to 1990 levels by 2020.  New Jersey – a densely populous state with limited renewable energy production – also added climate change legislation to its existing RPS requirements.  Under the new law, greenhouse gas emissions would be reduced approximately 15% below 1990 levels by 2020 and 80 percent by 2050. 

California and Washington already have both an RPS and climate change legislation.  While the mandates of all these states vary, they all push far into the future – 2050 – the most severe level of cuts, a move that may be reflect the technological challenges, but also resonates like a promise to start a diet tomorrow, or later. 

posted Monday, July 30, 2007 9:52 AM by Gunnar Birgisson

D.C. Circuit Strikes Down Rule Favorable to Waste-to-Energy Facilities

Dealing a blow to the waste-to-energy industry, a U.S. Appeals Court recently vacated a rule promulgated in 2004 by the Environmental Protection Agency (EPA) that implemented limits on emissions of hazardous air pollutants (HAP) from certain commercial and industrial boilers (the CISWI Rule). 

In 2005, a number of environmental organizations challenged the rule.  At particular issue was EPA's regulatory definition of "commercial and or industrial waste."  In short, EPA's definition limited solid waste incinerators, as a class, to those facilities (1) that operated without energy recovery or (2) whose design did not provide for energy recovery.  This interpretation effectively exempted waste-to-energy facilities from the HAP limitations contained within Section 129 of the Clean Air Act and allowed waste-to-energy facilities to be regulated by Section 112 of the Clean Air Act.  This distinction is significant because, among other things, the standards in Section 112 only apply to "major" sources of HAP emissions whereas Section 129 applies to all sources of HAP emissions. 

In rejecting the definition and vacating the rule, the court found that EPA's definition impermissibly "reduce[d] the number of commercial or industrial waste combustors subject to Section 129's standards by exempting from coverage any commercial or industrial incinerator combusting 'solid waste' if the combustion unit's design permits thermal recovery…."  Natural Resources Defense Council, et al. v. United States Environmental Protection Agency, No. 04-1385, slip op. at 14 (D.C. Cir. June 8, 2007).  Applying the traditional Chevron standard of review to EPA's regulatory definition, the court found that (1) Section 129 was intended unambiguously to cover any incineration facility that combusts any commercial or industrial solid waste and that (2) EPA's definition wrongly cabined the scope of this plain, broad language.  Barring an unlikely appeal, EPA will now need to craft a new definition that brings waste-to-energy facilities within the reach of Section 129.  The result will likely be regulatory uncertainty in the short term and more investment in HAP control technologies in the longer term
posted Monday, June 18, 2007 10:15 AM by Gunnar Birgisson

Department of Energy Proposes $9 Billion in Clean Energy Loans

Nine billion dollars could flow to guarantee loans to clean energy projects under a May 10 Department of Energy (DOE) Notice of Proposed Rulemaking (NOPR) under the Energy Policy Act of 2005. Each approved project could receive guarantees covering up to 80% of total project costs.  To be considered by the agency, written comments must be submitted within 45 days from notice in the Federal Register — likely late June or early July.

DOE proposes loan guarantees for ten categories of projects and technologies, including:  renewable energy systems; advanced fossil energy technology, including qualifying coal gasification systems; residential, industrial or transportation hydrogen fuel cell applications; advanced nuclear facilities, carbon capture and sequestration practices; efficiency in electrical generation, transmission and distribution; end-use efficiency technologies; production facilities for fuel efficient vehicles; pollution control equipment; and certain crude oil refineries.

Allocation of the $9 billion in loans will not be equally distributed among the ten categories; rather, $4 billion is reserved for central power stations, $4 billion for biofuels and clean transportation fuels, and only $1 billion for projects involving new technologies for electric transmission or renewable power generation systems.  According to DOE, precise allocation of the guarantees will depend upon the merits and benefits of a particular proposal and the accompanying statutory and regulatory requirements.

While the program is a positive development for the energy industry as a whole, efficient and fair implementation by DOE is critical, and that implementation is the specific subject-matter of the May 10 NOPR.  Provisions of particular interest to potential loan applicants include payment of the Credit Subsidy Cost, assessment of fees to loan recipients, rules on financial structure and eligibility of lenders, regulatory review, and default and audit rules.

Those industries now participating in eligible technologies and those planning expansion into clean energy projects can find public comment and public meeting procedures at Section III of the NOPR.

posted Monday, May 14, 2007 9:14 AM by Jennifer Rinker

Washington State Enacts Climate Change Legislation

Washington State has enacted a climate change law half a year after a ballot initiative approved a renewable portfolio standard (RPS).   The new law applies to long-term power-purchase agreements signed by utilities after July 1, 2008 and all new power projects built in the state after that time.   It requires that baseload generation comply with an emissions performance standard of 1,100 pounds of greenhouse gases  per MWh.  This is compatible with the emissions from state-of-art gas-fired generators, but would preclude long-term contracts with or development of coal-fired generation unless the greenhouse gases are sequestered or mitigated.  The law also establishes long-term greenhouse gas emissions reductions goals for the entire state.

The new law recites the state's vulnerability from climate change, including the potential impact on the snow pack that supplies summer stream flows and the effect of rising sea levels on coastal communities.  Under the existing RPS laws, affected utilities must procure 3% of their energy from renewables by 2012, 9% by 2015, and 15% by 2020, subject to different standards for utilities without load growth.  Most forms of renewable energy qualify as eligible sources, although hydropower is mostly excluded. 

How the greenhouse gas and RPS laws will work in tandem remains to be seen.  One impact is that new hydropower facilities could be used for compliance with the climate change law, but not with the renewable portfolio standard.  Washington State isn't the only state to have enacted both types of laws, as California has already gone down this path, and several other states with or without RPSs are working on various types of climate change proposals. 

In general, the two sets of legal requirements have some overlap, but also pursue different objectives.  A renewable portfolio standard doesn't by itself necessarily reduce overall carbon emissions, as it doesn't affect the type of generation that is not required to be renewable, i.e., the remaining 80% in an RPS that requires 20% renewable energy.  For example, if an RPS that requires 20% procurement of energy from renewable resources leads to wind and geothermal development that avoids CO2 emissions, the emissions of CO2 could still increase overall if the remaining 80% of generation includes emissions from sources such as coal-fired plants.  Conversely, setting CO2 limits without an RPS could lead to development of natural gas-fired generators with relatively low CO2 emissions, but would not necessarily promote renewable energy development.

posted Thursday, May 10, 2007 12:46 PM by Gunnar Birgisson

Supreme Court Rules that Carbon Emissions Are a Pollutant under the Clean Air Act

In a decision with potentially broad implications for the electric power industry, the Supreme Court ruled on April 2 that the Environmental Protection Agency was wrong when it declined to promulgate regulations to limit car and truck emissions of carbon as a greenhouse gas that contributes to global warming.  The case before the high court was confined to US automobile emissions; it did not directly address the far greater domestic carbon emissions from stationary, coal-fired power plants.   But the precedent established will surely fuel efforts to reduce power plant emissions either through a tax on carbon or an emissions cap-and-trade program.

In Massachusetts v. EPA (Case No. 05-1120), a harshly divided U.S. Supreme Court overturned EPA’s 2003 refusal to undertake a rulemaking to regulate carbon emissions from new motor vehicles under §202(a)(1) of the Clean Air Act.  Court patriarch, Justice Stevens (joined by Justices Kennedy, Souter, Ginsburg and Breyer) held that EPA’s denial of the petition should go back to Agency for reconsideration because EPA’s reasoning was not based on the requirements of the Clean Air Act.  The majority also rejected the government’s contention that the State of Massachusetts lacked sufficient interest (standing) to challenge EPA’s decision.  In dissent, Chief Justice Roberts (joined by Justices Scalia, Thomas and Alito), opposed what he called the majority’s  “special solicitude” to the State of Massachusetts, cautioning that the climate change grievances were tailored for redress by the Congress and the Chief Executive, not the federal courts.  Justice Scalia (joined by Chief Justice Roberts and Justices Thomas and Alito) separately dissented on the merits decision, arguing that EPA’s judgment on the petition to regulate carbon emissions was based on permissible reasons that warranted deference from the Court.

Nineteen private organizations petitioned EPA in 1999 for a rulemaking to regulate greenhouse gas emissions from new motor vehicles under §202 of the Clean Air Act.  (A dozen states (CA, CT, IL, ME, MA, NJ, NM, NY, OR, RI, VT and WA), local governments and others later joined in the petition.)  Section 202(a)(1) of the CAA requires EPA to prescribe by regulation “standards applicable to the emission of any air pollutant from . . . any class of new motor vehicles . . . which in the [EPA Administrator’s] judgment cause[s], or contribute[s] to, air pollution . . . reasonably . . . anticipated to endanger public heath or welfare.”  The CAA defines “air pollutant” to include “any air pollution agent . . . , including any physical, chemical . . . substance . . . emitted into . . . the ambient air.”

EPA denied the petition four years later because, in its view (1) the CAA does not authorize the agency to issue mandatory regulations to address global climate change, and (2) even if the agency had the authority to set greenhouse gas emission standards, it would nevertheless be unwise to do so at that time.  The U.S Court of Appeals for the District of Columbia Circuit affirmed.  Each of the three judges on the appeals panel wrote separately, but two (Randolph and Sentelle) agreed that EPA properly exercised its discretion in denying the rulemaking petition.  Judge Sentelle’s separate opinion also found that the petitioner’s failed to demonstrate standing in the case because a “particularized injury” could not be demonstrated where “global warming is harmful to humanity at large.”  

The United States Supreme Court heard oral arguments on November 29, 2006.  (In addition to EPA, respondents opposing Massachusetts and the petitioners were the Alliance of Automobile Manufacturers, National Automobile Dealers Association, Engine Manufacturers Association, Truck Manufacturers Association, CO2 Litigation Group, Utility Air Regulatory Group, and ten states (MI, AK, ID, KN, NB, ND, OH, SD, TX and UT).

Because the harm of greenhouse gasses is widespread, EPA argued it wasn’t a controversy specific enough to Massachusetts and the other petitioners to fall within the jurisdiction of the federal courts under Article III of the U.S. Constitution.  The Court majority disagreed because (i) Massachusetts held a special position and interest on behalf of its residents, (ii) the harms associated with climate change are serious and based on a strong consensus, (iii) EPA’s refusal to regulate carbon emissions from new cars, at a minimum contributes to injuries to Massachusetts’ coastal lands, and (iv) the delayed effectiveness of regulating only new motor vehicles and the concern that developing countries are poised to substantially increase greenhouse gas emissions does not excuse EPA from taking steps today to slow or reduce global warming.

The Court then reviewed the merits of EPA’s decision that it lacked authority to regulate new vehicle emissions because carbon dioxide is not an “air pollutant” under § 7602, and that, even if it possessed authority, it would decline to exercise it because regulation would conflict with other administration priorities.  The Court’s review of the merits of those decisions was narrow ¾ i.e., the Court would reverse only if its decision were found to be arbitrary, capricious, an abuse of discretion, or otherwise not in accordance with law.  Despite the narrowness of that review, the Court found that greenhouse gases fit well within the CAA’s capacious definition of “air pollutant” and that EPA’s contrary conclusion could not be squared with the statute.  The Court instructed that the law requires EPA to regulate an air pollutant if it causes or contributes to air pollution that may reasonably be anticipated to endanger public health or welfare; other policies cannot countermand that scientific judgment.

In dissent, Justice Scalia argued that the CAA says nothing at all about the reasons for which EPA may defer making a judgment on greenhouse gas emissions and that the Court should defer to EPA’s deferral.

Does this mean EPA will be forced to regulate carbon from car and truck emissions?  Not necessarily.  The question of whether is carbon is a pollutant subject to the Act is only a threshold question.  Now an analytical process begins on the road to establishing an administrative record on carbon.  Recall that the Clinton Administration in its Cannon memo argued that the Act covered carbon, but it never regulated or even proposed a carbon regulation.

If EPA did regulate car and truck emissions of carbon, would stationary source regulation be inevitable?  Stationary sources were not before the Court, and a separate administrative record would be required to establish a criteria document to regulate carbon from stationary sources.  That said, it is hard to imagine regulation of the 30 percent of US carbon emissions that come from cars and truck and ignoring the 70 percent that comes from stationary sources, primarily coal-fired electric generating stations.  Moreover, the balancing that EPA does for car and truck emissions allows for greater consideration of economic factors than does its stationary source program.

If the Agency decided to regulate, does that mean a cap?  Not necessarily.  There is little agreement over how to regulate carbon just yet.  Economists uniformly favor a tax because it is more efficient and enforceable, while coal-dependent electric utilities prefer a cap-and-trade program under which they would be allocated the lion’s share of allowances.  Acid rain (sulfur dioxide) is regulated pursuant to a cap/trade program.  But the acid rain program was a legislative compromise.  Before EPA actually regulates, there would likely be a Congressional enactment - just as there was for acid rain and ozone depletion.

Does this hurt the "public nuisance" climate change cases in the Second Circuit?  Some court-watchers believe that Justice Stevens was able to entice Justice Kennedy to join the 5-Justice majority for the petitioners by slicing the standing argument narrowly.  Justice Stevens differentiates Massachusetts from other potential parties in part by noting that States should be treated with special deference.  The Chief Justice warns that the majority is using an outdated view of standing to cobble its majority.

In the Second Circuit nuisance cases, a Rule 28(j) letter was filed only two days after the Supreme Court's decision, arguing (among other things) that the standing decision does not undermine defendant's arguments in the nuisance cases because the statutory right to challenge EPA's action was "of critical importance to the standing inquiry" in order to be asserted "without meeting all the normal standards of redressability and immediacy."  The 28(j) filing also argues that the States' sovereign prerogatives to force reductions in greenhouse gases "now lodged in the Federal Government," and that "Congress has ordered EPA to protect" States from harms associated with those emissions.  And thus, that the narrow federal common law cause of action to abate nuisances is not a remedy for complex environmental issues, and cannot be expanded given Congress's authority.

posted Monday, April 09, 2007 1:26 PM by Gunnar Birgisson

Texas Legislature Considers Tax Incentives Aimed at Greenhouse Gas Emissions

On the heels of efforts in California to reduce greenhouse gas emissions by limiting the amount of coal-generated power that in-state utilities may purchase, members of the Texas Legislature are similarly aiming to provide incentives for energy companies to reduce greenhouse gas emissions and use cleaner technologies.  Proposed House Bill 270, introduced by Rep. Rafael Anchia (D-Dallas), would impose a 7.5 percent tax on coal purchased in Texas for use in the state.  The revenue raised from the new tax would be used to promote new energy technologies.  Currently, H.B. 270 is pending in the House Regulated Industries Committee.  Another proposed bill, H.B. 3431, introduced by Rep. Mark Strama (D-Travis Co.) and currently being considered by the House Ways and Means Committee, would exempt from property taxes any pollution controls installed to reduce carbon dioxide emissions in enhanced oil recovery projects.  This bill would also reduce by half the tax on oil produced in the state if carbon dioxide is used in the recovery.  The current Texas legislative session ends May 28.
posted Friday, March 30, 2007 5:06 PM by Tracy Davis

Western Governors Increase Efforts to Coordinate Emissions Control

The governors of five western states have established the Western Regional Climate Action Initiative to pursue a joint effort to combat greenhouse gas emissions.  Pursuant to a Memorandum of Understanding, Washington, Oregon, California, Arizona and New Mexico will set regional targets for reducing greenhouse gases within the next six months, and plan to develop a market-based program, such as a load-based cap-and-trade program, to reach those targets, over the next eighteen months.  Additional goals of the Initiative include developing a multi-state greenhouse gas registry to facilitate tracking, management, and crediting for entities that reduce emissions, promoting renewable energy use and increasing energy efficiency within the five states, and advocating for western states' needs and interests in regional and national climate policy debates. 

The Initiative has a good head start on these tasks, as it can build on the individual efforts of these states to reduce greenhouse gas emissions that are already in place, including renewable portfolio standards, emissions reporting, and two existing regional efforts, the West Coast Global Warming Initiative that California and Washington established in 2003, and the Southwest Climate Change Initiative Arizona and New Mexico launched in 2006. 

The Initiative is the latest of a growing number of examples of states and regions taking actions to curb greenhouse gas emissions as discussions of nationwide emissions standards are still in their nascent stages.  At the announcement of the Initiative's creation, the five governors pointed to increases in drought periods, decreased snowfall, earlier snowmelt, and more severe forest and rangeland fires as threats to their economies which depend heavily on tourism, snow-sports, agriculture and livestock.  Due to similar concerns in neighboring Utah, Utah's governor has stated he will consider joining the Initiative as well.
posted Thursday, March 08, 2007 12:05 PM by Andrea Kells

EEI, EPSA Endorse National Mandate on Greenhouse Gas Emissions

Last week EPSA and EEI became the first major energy trade groups to advocate a federal mandate to control greenhouse gas emissions.  Both groups' endorsements of national emissions  legislation are predicated on sets of guiding principles reflecting the interests of their members.  EPSA's statement indicated its concern that programs currently being implemented or developed in states across the country, with their differing and inconsistent demands, will present compliance difficulties for utilities and power generators.  EPSA hopes that a federal mandate will preempt the state programs and achieve consistency across states and regions.  At the same time, EPSA emphasized that national carbon control legislation should ensure that funding and incentives for carbon emission-reducing technology are available to industry participants on a competitive basis.  

EEI's new global warming principles represent a departure from EEI’s past opposition to carbon taxes and mandatory greenhouse gas emissions caps.  EEI's new policy advocates carbon legislation that ensures the development of a range of “climate-friendly” technologies, minimizes disruptions to consumers and the economy, and applies to all sectors of the economy, including transportation.  Beneath these general principles, however, EEI's membership remains divided on major issues such as how to allocate carbon emission allowances to electric utilities and other industrial emission sources. 

Neither industry group has endorsed any of the specific carbon control bills working their way through Congress.  Nor have they advocated for specific greenhouse gas reduction levels or timetables.  These statements of support for a national greenhouse gas emissions mandate, however, reflect a shift in industry thinking.  With increasing numbers of climate change-related bills before Congress, and the steady drumbeat of  demands that global warming be reversed ─ including EEI Chairman and Duke Energy President, Chairman, and CEO James Rogers' recently-announced support for the U.S. Climate Action Partnership ─  regulated utilities as well as generators have apparently concluded to take a seat at the table before negotiations approach end game.

posted Thursday, February 15, 2007 1:28 PM by Andrea Kells

California PUC Takes Steps Towards Reducing State's Emissions

In an effort to comply with a new state law limiting carbon dioxide and other greenhouse gas (GHG) emissions in California, on January 25 the California Public Utilities Commission (CPUC) adopted an interim Greenhouse Gas Emissions Performance Standard.  The interim standard requires the state's energy providers to source their power supply from plants that emit less than 1,100 pounds of CO2 per megawatt hour whenever they enter into any new or renewed power purchase commitments of five years or more.  That emission rate is equivalent to the CO2 emitted from a combined-cycle natural gas turbine.  Construction of new power plants and major investments by utilities in existing power plants would also be subject to the standard.  The interim standard will be in place until the CPUC can establish a permanent, enforceable load-based GHG emissions standard.

The CPUC's decision was seen as a challenge to traditional coal-fired generators whose CO2 emissions would not meet the interim standard, particularly those located outside the state that sell into California markets.  At present, California gets approximately 20% of its power from traditional coal plants that are located outside the state.  Clean coal plants with CO2 controls would be able to meet the interim standard.

posted Friday, February 02, 2007 10:10 AM by Tracy Davis

California Enacts More Aggressive RPS Plan

There are growing concerns that due to transmission constraints and cumbersome regulatory procedures, California will struggle to meet the requirements of its renewable portfolio standard (RPS) legislation.  Nevertheless, in a sign of the state's ambition, Gov. Schwarzenegger recently signed into law an even stricter RPS standard.

Under the new law, the state's retail providers (excluding municipal utilities) must obtain 20% of their power from renewable energy by the year 2010, instead of 2017.  However, another aspect of the law may make the utilities' challenge less onerous.  Until now, California regulators have not authorized the use of renewable energy credits (RECs) to meet RPS requirements, but the new law allows the state's Public Utilities Commission and Energy Commission to develop such a system of credits.  In addition, renewable energy from outside the state may now become eligible to help meet RPS requirements.  These provisions are likely to help integrate western renewable energy markets.

Recently, the state also enacted laws requiring a reduction in greenhouse gas emissions, and requiring the Energy Commission to address the capture and sequestration of industrial carbon dioxide.  It remains to be seen how these laws will complement each other. 
posted Friday, October 06, 2006 10:28 AM by Gunnar Birgisson

Replacing, Not Prolonging, Old Power Plants Is Policy of Clean Air Act, 7th Circuit Rules

In an August 17 decision, the United States Court of Appeals for the Seventh Circuit ruled that Cinergy Corp. violated the Clean Air Act by upgrading coal-fired power plants in Ohio, Indiana, and Kentucky in the late 1980s and early 1990s without installing controls to capture pollution and without updating its federal air pollution permit.  Judge Richard Posner’s decision perpetuates a deep split among federal appellate courts on how to interpret the  New Source Review (NSR) provisions of the Clean Air Act.  In particular, the Seventh Circuit's Cinergy decision conflicts with a 2005 Fourth Circuit decision that found that Duke Energy had not violated the NSR when it similarly upgraded power plants.  The U.S. Supreme Court has granted certiorari in the Duke case, and is expected to issue a decision in that case in early 2007.

NSR is a federal permitting program, enacted as part of the Clean Air Act in the late 1970s.  It requires power plants, factories, and other industrial facilities to obtain permits before constructing new facilities or adding on to existing ones.  The program is aimed at ensuring that plant additions and expansions do not degrade local air quality.  The primary issue in both the Cinergy and Duke cases involved whether particular actions by the utilities triggered the NSR requirements.  Specifically, both courts were called on to interpret the meaning of the phrase "emissions increase" for purposes of the NSR program, and to determine whether the utilities' actions can be considered "routine maintenance," which is exempt from NSR, or are "major modifications," which would require new federal permits and the installation of improved air quality controls. 

Duke and Cinergy both argued that NSR's pollution control requirements are triggered by increases in hourly emissions rates — which were virtually unchanged in both cases — and that the "routine maintenance" exemption refers to activities that are routine within the industry.  The Environmental Protection Agency ("EPA"), on the other hand, contended that NSR requirements are triggered by increases in annual emissions, and that "routine maintenance" refers to maintenance activities that are routine for a specific generating unit.  The Seventh Circuit in Cinergy sided with the EPA, reasoning that Cinergy's interpretation of the NSR provisions would give utilities an "artificial incentive" to renovate a power plant and continue using it beyond its expected lifespan, rather than replacing it with a more environmentally friendly plant.  According to Judge Posner, that incentive conflicted with the intent of the Clean Air Act.

posted Monday, September 11, 2006 8:10 AM by Tracy Davis

First in Nation, California Set to Mandate Greenhouse Gas Reductions

California is poised to become the first US jurisdiction to mandate reductions of greenhouse gas (GHG) emissions as soon as Gov. Schwarzenegger signs the California Global Warming Solutions Act of 2006, which he negotiated with the state legislature,  By 2020 the bill would require GHG emissions be reduced to 1990 levels in the state.  Whether the reductions program will include market-based emissions trading favored by industrial interests is unclear.

The bill does not specify a given percentage level reduction of GHG emissions reductions, but requires reduction to a 1990 emission baseline that the California Air Resource Board (CARB)  is to establish.  Much of the detail is left to the CARB's implementation process, which includes adoption of rules and regulations by January 1, 2008.  Regulations for achieving the GHG emissions goals are to take into account many salutary but seemingly incompatible considerations.  These include equitable distribution of emissions allowances, avoiding disproportionate impacts on low-income communities, crediting entities that have already voluntarily reduced emissions, maintaining existing air quality standards, costs and benefits, minimization of administrative burdens, minimization of leakage (a reduction of GHG emissions in-state that is offset by an increase elsewhere), and consideration of the contribution of different sources of GHG emissions. 

By June 30, 2007, the CARB is to issue a list of discrete GHC reduction measures that can be implemented before other measures; by January 1, 2010, the CARB is to adopt regulations to implement those early measures.  Emission sources would have to start GHG reporting in 2008, and the CARB would start enforcing GHG emissions reductions by January 1, 2012.

Gov. Schwarzenegger earlier signed an agreement with British Prime Minister Tony Blair committing California and the United Kingdom to cooperate in battling climate change and promoting energy diversity.  The agreement calls for cooperation on technologies, sharing data, and developing market-based incentives. 

posted Thursday, September 07, 2006 10:14 AM by Gunnar Birgisson

California PUC Judge Rules that LNG Must Meet Air Quality Standards

In a state proceeding addressing the increasingly important issue of natural gas interchangeability, a California Public Utilities Commission ("CPUC") Administrative Law Judge recommended that utilities must ensure that burning of future liquefied natural gas ("LNG") imports, which may have a higher heat rate than other supplies, meets the current applicable emissions requirements.

The proceeding was prompted by concerns about the adequacy of natural gas supplies and infrastructure in California.  As in other parts of the country, imported LNG is expected to help meet growing demand.  In the context of the applicable gas quality standards, utilities San Diego Gas & Electric and its affiliate Southern California Gas Co. asked the CPUC to accept revised gas quality specifications, including a Wobbe Index value (which is related to the gas' heat rate), due to the requirements of future LNG imports, which differ from current natural gas standards.  The South Coast Air Quality Management District, which is the agency responsible for reversing the non-attainment status of the South Coast Air Basin, objected to the utilities' proposal, arguing that future LNG imports are expected to have a higher heat rate and may lead to an increase in emissions from household and industrial equipment and from vehicles that run on compressed natural gas.  The ALJ recommended minor rule changes but otherwise proposed that utilities comply with existing standards and submit an environmental assessment for any proposed deviations from those standards.  The ALJ also would require CPUC staff to conduct studies related to gas quality standards.

Volunteers for Green House Gas Reductions Not Volunteering

After determining the U.S. would not participate in the Kyoto treaty on global warming, the Bush Administration pursued other measures to limit climate-warming greenhouse gas (GHG) emissions, including two non-binding programs that US industry could volunteer to participate in.  In 2002, the Environmental Protection Agency offered the Climate Leaders program, and in 2003 the Department of Energy offered the awkwardly named Climate VISION (Voluntary Innovative Sector Initiatives: Opportunities Now).  In a recent report prepared for Senators John McCain (R-AZ) and John Kerry (D-MA), who are cosponsors of legislation that would set mandatory caps on GHG emissions, the U.S. Government Accountability Office concluded that both programs lack leadership and vision, not to mention accountability. 

Both Leaders and VISION contemplate that participants or their trade group representative set goals to reduce either total GHG emissions or emissions intensity (emissions per unit of output) below a base line.  According to GAO, however, as of late 2005, less than half of the 85 participants in EPA’s Leaders program had even set an emissions reduction goal, and only 5 had achieved them.  Moreover, EPA has no position or policy on what the consequences should be for not completing the project step on schedule.   While 14 of 15 trade association participants in DOE’s VISION program have set goals (which are not binding on members), DOE has no standard for determining baseline emissions and no procedures for tracking a participant’s progress toward its goal.  And like EPA, DOE never articulated the consequences for failing to make progress. 

In a paradigm of understatement, GAO opined that “to demonstrate the value of voluntary programs — as opposed to mandatory reductions — the agencies will need robust estimates of the programs’ effect on reducing emissions.”  Neither EPA nor DOE can produce even anemic estimates of emissions reductions. 

What stands out from the GAO report to Senators McCain and Kerry is the sparse participation by electric utilities.  While there are some notable participants, including AEP, PSEG, Entergy and Exelon, from this sector, which is the highest emitter of carbon dioxide, many other major utility emitters do not individually participate in these programs.   Public power may be poised to reverse this poor utility participation with the recent announcement that it has launched a “blue-ribbon, CEO-level task force to study global warming and to develop recommendations for dealing with it.”  It remains to be seen whether this study will result in reductions.
posted Tuesday, June 20, 2006 4:23 PM by David Nosse

Seven States Vie to Host FutureGen Alliance "Clean Coal" Power Plant

Seven states have reportedly submitted bids to host a proposed zero-emissions coal-fueled generation facility, the developer FutureGen Industrial Alliance announced on May 9.  The proposed 275 MW plant would burn gasified coal to produce electricity and transportation-grade hydrogen for use in fuel cells.  Carbon dioxide waste generated by the plant, normally vented into the air, would either be sequestered or stored underground.  See Alliance Starts Site Selection for Zero-Emissions Coal Plant.  FutureGen reported that Illinois, Ohio, Texas, Kentucky, North Dakota, West Virginia, and Wyoming all submitted bids; some of the states submitted bids for more than one site, bringing the total number of sites under consideration up to twelve.  FutureGen indicated it would review the proposals, come up with a short list of candidates by this summer, and make a final site determination by late summer 2007.

A poster child for the Bush administration's energy policy, the project will receive significant funding from the federal government.  In 2004, Congress appropriated up to $700 million to build and operate the plant through 2018 and to sequester its carbon emissions.  Further financial support will be provided by a coalition of industry participants, including two foreign-owned companies, representing Australian and Chinese coal interests.  The governments of India and China also have each agreed to provide $10 million for the development of the prototype.  Both countries are desperately in need of energy, and are hoping their investment will pay dividends in the form of relatively clean future coal plants in their respective countries.

posted Thursday, May 18, 2006 12:15 PM by Tracy Davis

Economic Escape Valve to Moderate Maryland's Tough Emissions Law

The Healthy Air Act  that Maryland Governor Ehrlich signed into law in early April requires seven Maryland power plants to reduce their emissions of sulfur dioxide by 90% by 2015; nitrogen oxides by 80% by 2015; and mercury by 80 % by 2010 and by 90% by 2012.  The law also requires Maryland to join the Regional Greenhouse Gas Initiative, a compact of seven northeastern and middle Atlantic states that have pledged to cut 10 % of  their carbon dioxide emissions by 2018. 

While these requirements represent one of the toughest emissions laws to be enacted to date in the United States, the law also contains an escape valve:  Maryland's Department of the Environment is authorized to reduce or waive penalties for plants that fail to reach the targets based on a determination that the cost of pollution controls required to comply with the law would "significantly increase electric rates." 

With the new law, Maryland joins Massachusetts, New Hampshire, and North Carolina as the only states to enact laws requiring comparable reductions of multiple pollutants.  The law's passage, however, comes at the same time as Maryland consumers and utilities struggle with the implementation of industry deregulation and the attendant power price increases – a juxtaposition that, together with the new law's economic waiver provision, may decrease the effectiveness of the Health Air Act in curbing emissions.
posted Wednesday, April 19, 2006 5:42 PM by Andrea Kells

Ohio Regulators Provide Ratepayer Funding for AEP Clean Coal Plant

The Public Utilities Commission of Ohio (PUCO) has granted AEP the authority to recover in rates construction costs up to $23.7 million related to its proposed integrated gasification clean coal (IGCC) plant.  Critics argued that the PUCO should not allow AEP to recover its costs through rates in a deregulated electric power market such as Ohio's.  In response, AEP countered that it needed the generation to serve as provider of last resort to consumers in its Ohio service territory; thus granting it the ability to recover the IGCC costs in rates was justified.  The PUCO agreed. 

AEP next will need to respond to PUCO inquiries about the plant's rate structure, the benefits to consumers, the amount of local coal, the production and sale of byproducts of the combustion process, and the extent to which AEP can take advantage of federal and state IGCC incentives.  AEP plans to submit the requested information in October 2006, but harbors concerns that another long round of evidentiary proceedings on these issues could cause it to miss the 2010 in-service deadline imposed by its provider of last resort obligations. 

Only two other IGCC plants are currently in operation within the U.S., and those were built as demonstration projects with hefty federal subsidies.  Realizing the full potential of IGCC technology may require more state authorities to follow the PUCO's lead in facilitating rate recovery of project costs.
posted Thursday, April 13, 2006 4:43 PM by Andrea Robinson

Mass Legislators Revive Fight over Participation in Northeast Emissions Reduction Plan

Balking at Governor Mitt Romney's opposition, members of the Massachusetts legislature recently introduced a petition for legislation to reduce carbon dioxide emissions in Massachusetts through participation in the Regional Greenhouse Gas Initiative (RGGI), a regional cap-and-trade program intended to reduce greenhouse gases in the Northeast.  However, because of concerns over the program's effect on electricity prices, it is questionable whether the bill can be passed before the state legislative session ends in July 2. A two-thirds majority vote of the legislators would be needed to override the Governor's anticipated veto.

In December 2005, in a move reminiscent of the Bush Administration's rejection of the Kyoto Protocols, Governor Romney announced that Massachusetts would remove itself from participation in the RGGI, but would pursue its own carbon dioxide emissions reduction plan, which went into effect on January 1, 2006.  (See Mass. Governor Announces New Carbon Dioxide Emissions Reduction Plan) The state's current plan includes a cap-and-trade system, but without price caps.

Because Massachusetts is a key contributor of gas emissions in the Northeast region, its participation in the RGGI is significant.  Currently, all other New England states, save tiny Rhode Island, which also dropped out of the RGGI plan in December 2005, have a formal agreement in place to pursue the RGGI and are now moving forward on legislation to adopt the RGGI.

posted Monday, March 20, 2006 4:02 PM by Jackie Java

EPA, Midwestern Blue Skyways Collaborative to Promote Renewable Power

The US EPA and several Midwestern states have formed a collaborative to begin curbing polluting emissions through voluntary measures.  The "Blue Skyways Collaborative" held its inaugural meeting last month, welcoming a diverse group of participants including representatives from EPA, the Departments of Defense and Energy, state and local officials, and corporate representatives.  It is spearheaded by the Central States Air Resource Agencies (CenSARA), the regional air planning organization for the Midwest, comprising Minnesota, Iowa, Nebraska, Kansas, Missouri, Oklahoma, Arkansas, Louisiana, and Texas.   

The Collaborative hopes to reduce emissions along major Midwestern transportation corridors and in various sectors, including aviation, water and rail transport, on-road diesel vehicles, and heavy off-road equipment, through retrofitting diesel-powered vehicles and encouraging renewable energy and energy efficiency projects.  A focus on renewable power sources sets this initiative apart from other regional voluntary emissions-reducing efforts, and reflects the regional economic interest of Collaborative participants in spurring use of ethanol and biodiesel, both of which derive from corn and other regional crops.   

While it has yet to establish numerical emissions reduction targets, the Collaborative's first meeting showcased the types of voluntary efforts and public-private initiatives that it hopes to foster.  For example, railroad industry representatives described their efforts to replace diesel-burning switch-engines with battery-operated engines.  The EPA has promised a modest $9 million to finance the Collaborative's projects this year, and the group anticipates several times that amount for 2007 financing.  Whether Blue Skyways proves successful likely will depend on whether this federal funding materializes ¾ a questionable proposition in light of the Administration's and Congress' recent failures to adequately fund the clean energy initiatives that they only recently enacted in the Energy Policy Act of 2005.

posted Friday, March 17, 2006 10:41 AM by Andrea Robinson

Alliance Starts Site Selection for Zero-Emissions Coal Plant

The coal and electric utility industries in the FutureGen Alliance have started selecting a site for the state-of-the-art FutureGen project, a coal-fired, zero-emissions power plant the Alliance will build in cooperation with the U.S. Government.  If successful, the project may devise ways of harnessing abundant U.S. and world coal reserves without exacerbating the world’s increasingly worrisome dynamic of greenhouse gas emissions overheating the global climate.  

Members of the Alliance include two large U.S. utilities, American Electric Power and Southern Company, as well as BHP Billiton, the China Huaneng Group, CONSOL Energy Inc., Foundation Coal, Kennecott Energy, and Peabody Energy.  They will pay a portion of the plant's costs, while the U.S. government, acting through the DOE, will fund the balance.  The Alliance has announced it will issue a request for proposals in March 2006 for selection of the site for the project.  A draft RFP is already available.  Candidate sites will be evaluated based on technical, environmental, regulatory and financial criteria.  In addition to possessing the usual attributes that are keys to successful power plant siting, such as the availability of water, transmission, and fuel delivery, potential sites must be in an area where the geology is amenable to sequestration of carbon dioxide for permanent storage.  The Alliance expects to select a site by late 2007.  With lengthy periods expected for permitting and construction, the plant is unlikely to be operational before 2012. 

The DOE will serve as lead agency in preparing an environmental impact statement (EIS), pursuant to the National Environmental Policy Act (NEPA), to determine which of the candidate sites are acceptable from an environmental impact perspective.  Comments related to the NEPA process are due to DOE by March 20, 2006.  

posted Monday, February 27, 2006 10:35 AM by Gunnar Birgisson

Illinois Joins States Reducing Mercury Emissions

Earlier this month, Illinois Governor Rod Blagojevich (D) announced he would mandate reductions in mercury emissions from the state's 22 coal-fired power plants by 90 percent by June 30, 2009, joining Connecticut, New Jersey, Maryland, Massachusetts, Minnesota, North Carolina and Wisconsin, in calling for mercury reductions stricter than those called for by the U.S. Environmental Protection Agency in its March 10, 2005 Clean Air Mercury Rule.  The EPA Rule calls for reductions of 47 percent by 2010 and 79 percent by 2018.  Power plants emit approximately 43 percent of mercury emissions in the United States, making power plants the leading man-made source of mercury emissions.

Lauded by environmentalists, Governor Blagojevich's proposal is the most aggressive in the nation: mercury emissions must be reduced by an average of 90 percent by June 30, 2009, and each coal-fired plant is required to reduce emissions by 75 percent by 2009 and by 90 percent by the end of 2012.  Under the Governor's plan, practices that permit plants to get around emissions controls, such as purchasing allowances or trading emissions credits with other companies or states, are prohibited.  The proposal will go before the Illinois Pollution Control Board in February, and if adopted, could become a model for other major coal-producing states considering mercury emissions reductions.  [See Maryland Governor Proposes Plan to Reduce Plant Emissions]

posted Tuesday, January 24, 2006 12:23 PM by Jackie Java

Mass. Governor Announces New Carbon Dioxide Emissions Reduction Plan

After pulling out of the Regional Greenhouse Gas Initiative (RGGI) earlier this month, Massachusetts Gov. Mitt Romney (R) announced that the Bay State would pursue its own new carbon dioxide emissions (CO2) reduction plan.  The reductions go into effect January 1, 2006, but power generators will not be required to comply until 2007.

In particular, the plan targets Massachusetts' six oldest coal- and oil-fired power plants.  It calls for generators to cap emissions at 1997-99 levels, and includes a production limit of 1800 pounds/MWh.  The Governor's plan allows generators to meet limits by finding offsets in the Northeast region.  Additionally, the plan provides a "safety valve" meant to guard against excessive price increases:  If the price of available offsets reaches $6.50/ton for 12 months, then the generators would be able to shop for offsets anywhere in the world, and if the price reaches $10/ton, they could meet their obligations by paying into a new Greenhouse Gas Expendable Trust.  The money in the trust would be used to invest in CO2 emission offset projects.  The plan also includes reductions for sulfur dioxide, nitrogen oxides, and mercury.

Gov. Romney's intent is to work side-by-side with the RGGI, which is an emissions reduction work-in-progress of nine Northeastern states, and includes a cap-and-trade system, without price caps.  The Governor explained that if Massachusetts joins the RGGI,  its regulations could be modified to act in coordination with RGGI's plan.  However, critics of the Governor's plan claim that it is not compatible with the RGGI plan, and that the RGGI plan would better protect ratepayers by auctioning allowances and using the money for energy efficiency improvements, instead of allowing plant owners to avoid pollution reductions by paying a fee.

posted Thursday, December 22, 2005 1:45 PM by Jackie Java

Two Paths to a Future Powered by Integrated Gasification Combined Cycle

Both California and Pennsylvania recently put forward energy plans that are likely to speed implementation of highly efficient and low-polluting technologies for generating electricity from gasified coal.  The 2005 Integrated Energy Policy that the California Energy Commission ("CEC") adopted at the end of November would indirectly have this effect by requiring the Golden State's utilities to procure power only from generating stations that meet Governor Schwarzenegger's (R) greenhouse gas ("GHG") performance standards, which integrated gasification combined cycle ("IGCC") units can but traditional coal-fired plants cannot.  Fast on the heals of the CEC Policy, Pennsylvania Governor Rendell (D) unveiled his Energy Deployment for a Growing Economy ("EDGE") initiative to provide low-interest loans for IGCC units and a moratorium on required pollution controls on existing coal-fired plants whose owners commit before 2007 to install IGCC by the beginning of 2013.  The Rendell proposal likely will require Environmental Protection Agency ("EPA") approval of the moratorium on pollution controls at existing plants as that would extend by two years the 2010 emission reduction directive of EPA's recently announced Clean Air Interstate Rule ("CAIR").

California is the 6th largest economy in the world and the 17th largest emitter of GHG.  Every two years the CEC updates California's energy plan.  The 2005 plan imposes on utility power procurements the GHG performance standards that Governor Schwarzenegger established last June.  Those standard aim to reduce GHG emissions to 2000 levels by 2010, to 1990 levels by 2020, and to 80 percent of 1990 levels by 2050.  These standards effectively rule out procurements from traditional coal-fired plants and cast into doubt the viability of several dozen non-IGCC coal-fired projects (including some under construction) that are designed to serve the enormous California market.  Another project targeted to the California electricity market, the 1,300-mile Frontier transmission line that would link Powder River Basin coal deposits in Wyoming with California, may also be jeopardized by implementation of the GHG performance standards.

Because the capital cost of an IGCC plant runs 20-plus percent higher than for a traditional coal-fired unit, some have predicted that, in order to access the abundant coal reserves in the west, California would likely need to invest in some early IGCC plants to help demonstrate and establish the technology.  But then comes along the Pennsylvania initiative.  If it garners EPA buy in, EDGE could provide precisely the stimulus that IGCC requires, not only in Pennsylvania and California, but also in other markets with abundant coal reserves.   The program will give new and retrofit IGCC projects priority access to nearly $ 1 billion in low-interest loans form the Keystone State's Economic Development Financing and Energy Development Authorities.  Two of the leading IGCC technology providers, General Electric and Shell Oil, have committed to Governor Rendell that they will guarantee the performance of their equipment in connection with the EDGE program.

Nearly 10 percent of Pennsylvania electric generation capacity is coal-fired units that will need to discontinue operations or invest in costly pollution controls beginning in 2010 under CAIR.  [See Maryland Governor Proposes Plan to Reduce Plant Emissions] Each of these will be a candidate for conversion to IGCC under Governor Rendell's initiative.  When coal is gasified pollutants can be removed more economically and efficiently than they can be removed from the pulverized coal burned in traditional plants.  IGCC plants also emit significantly less carbon dioxide, the GHG principally responsible for global warming.

posted Thursday, December 01, 2005 7:12 PM by Jackie Java

Maryland Governor Proposes Plan to Reduce Plant Emissions

Earlier this month, Maryland Governor Erlich (R) proposed the Maryland Clean Power Rule ("MCP Rule"), which would mandate constant emission controls and greatly diminish nitrogen oxide (NOx), sulfur dioxide (SO2) and mercury emissions from Maryland power plants, years ahead of the U.S. Environmental Protection Agency's Clean Air Interstate Rule (CAIR) and Clean Air Mercury Rule.  Under the MCP Rule, by 2010, NOx emissions would be reduced by 45,000 tons per year (69%); SO2 emissions would be reduced by 205,000 tons per year (85%); and mercury emissions would be reduced by 1,400 pounds per year (70%), with a second phase of controls reducing mercury emissions by 90% by 2018.  The limits imposed by the MCP Rule also would help cut fine particulate matter emissions and help the state to meet federal standards, as called for in CAIR by 2010.

The MCP Rule's emission limits would have the biggest impact on Maryland's six largest coal-fired power stations, three of which are owned by Constellation Energy and three by Mirant. According to the Governor's office, these six stations produce 95% of the state's power plant emissions.   Under the MCP Rule, plants would have to add pollution controls to meet the emission reductions instead of buying out-of-state emissions allowances.  Companies would be permitted to average emissions among their plants, but would not be able to trade with other companies.

The MCP Rule is expected to be published in the Maryland Register sometime in early 2006 and hearings on it will be held in the spring by the state's Department of Environment.

posted Thursday, December 01, 2005 10:29 AM by Jackie Java

Congress Enacts Energy Bill

One month after the Senate approved its version of a comprehensive energy bill, see Senate Votes in Favor of Energy Bill, Tumultuous Conference Awaits, Congress enacted the Energy Policy Act of 2005.  Although maligned by energy and taxpayer watchdogs as a "piñata of perks and pork" for big oil, big nuclear and other entrenched energy industries, the 2005 Act, as it affects certain aspects of the power and natural gas industries, promises to profoundly change the structure and prospects of new energy business organizations and the viability of new liquefied natural gas and power transmission projects.

For several years the demand for relatively clean-burning natural gas has increasingly outstripped North American production, giving impetus to efforts to import liquefied natural gas ("LNG").  But concerns over the safety of LNG re-gasification facilities in this country, both on- and off-shore, have seen myriad LNG development proposals from coast-to-coast crash in the face of public opposition.  The 2005 Act will override that opposition in part by consolidating many of the needed approvals, including siting, in one agency – FERC.  State and local authorities are effectively stripped of authority to block the siting of LNG importing and processing facilities.

The 2005 Act also promises to effect fu