Electric Market National Overview
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1 Electric Market Overview Electric Market National Overview 1122
2 Electric Market Overview: Generation Output and Temperatures Page 2 of 8 Weekly U.S. Electric Generation Output and Temperatures Electric Generation (GWh) 100,000 90,000 80,000 70,000 60,000 50, Range 2007 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2007 Warmer Temperatures than Normal (Degree Days) Heating Season Cooling Season Heating Season Source: Derived from EEI and NOAA data. 1110
3 Electric Market Overview: Financial Market Volumes Page 3 of 8 Financial Trading on ICE Source: Derived from ICE data. ICE on-peak swap volumes include monthly, dual monthly, quarterly, and calendar year contracts traded for each month. Thousands of GWh PJM Jan-06 Feb-06 NEPOOL SP-15 NYISO J Mid-C NYISO A Cinergy NYISO G Palo Verde NP-15 Mar-06 Apr-06 May-06 Jun-06 Jul-06 Aug-06 Sep-06 Oct-06 Nov-06 Dec-06 Jan-07 Feb-07 Mar-07 Apr-07 May
4 Electric Market Overview: Renewables Page 4 of 8 Renewable Energy Portfolio Standards (RPS) A RPS requires a percent of energy sales or installed capacity to come from renewable resources. 22 states and DC have renewable energy standards. Three have goals only. New Hampshire passed an RPS in April. Virginia s restructuring law set an RPS goal for utilities, with financial incentives. States that adopted transmission planning and cost recovery policies to support new renewable generation include California, Colorado, Minnesota, New Mexico and Texas. MT: 15% by 2015 WA: 15% by 2020 OR: proposed: 25% by 2025 NV: 20% by 2015; solar 5% per year CA: 20% by 2010 IA: 2% by 2011 AZ: 15% by 2025, of which 30% is distributed NM: 20% by 2020; adds co-ops 10% by 2020 HI: 20% by 2020 MN: 25% by 2025 * CO: 20% by 2020, including 4% annual solar; adds co-ops and munis WI: 10% by 2015 IL: 8% by 2013 TX: 5,880 MW by 2015 IN: 10% by 2017 VT: growth up to 10%, MO: proposed OH: 20% by % goal by 2020 Existing RPS Strengthened/ amended RPS RPS with additional goals Proposed RPS ME: 30% by 2000 NH: 25% by 2025 MA: 4% by 2009 RI: 16% by 2019 CT:10% by 2010 NY: 24% by 2013 NJ: 20% by 2020; plus 2% solar DE: 10% by 2019 PA: 18% by 2020 MD: 9% by 2022, including 2% solar DC: 11% by 2022 VA: 12% by 2022, with financial incentives * Minnesota s requirement for Xcel Energy exceeds the state RPS; it is 30% by Sources: Derived from data in: EEI, EIA, LBNL, PUCs, State legislative tracking services, Database of State Incentives for Renewables and Efficiency, and the Union of Concerned Scientists. Voluntary standards or goals 1109
5 National Electric Market Overview: Coal Prices Page 5 of 8 Central Appalachian and Powder River Basin Coal Prices $70 $60 $50 $40 $30 $20 $10 $0 Jan-06 Feb-06 Source: Derived from Bloomberg data. Prices ($/ton) Central Appalachian Powder River Basin Mar-06 Apr-06 May-06 Jun-06 Jul-06 Aug-06 Sep-06 Oct-06 Nov-06 Dec-06 Jan-07 Feb-07 Mar-07 Apr-07 May
6 National Electric Market Overview: Emission Allowance Prices Page 6 of 8 $3,000 SO 2 and NO x Allowance Spot Prices $2,500 SO2 Spot Price NOx Spot Prices Prices ($/ton $2,000 $1,500 $1,000 $500 $0 Jan-06 Feb-06 Source: Derived from Cantor Fitzgerald data. Mar-06 Apr-06 May-06 Jun-06 Jul-06 Aug-06 Sep-06 Oct-06 Nov-06 Dec-06 Jan-07 Feb-07 Mar-07 Apr-07 May
7 Emissions Market: Emission Allowance Prices Page 7 of 8 SO 2 In the 2006 EPA-administered SO 2 auction, merchants and retirement funds won more than 98% of the 125, SO 2 spot allowances available for auction. Virtually no traditional investor owned utilities bid into this auction SO 2 spot allowance prices peaked on January 3rd at $1,583/ton. Allowance prices dropped to $465/ton on November 21st their lowest price in SO 2 spot closed the year at $483/ton on December 29th. Factors contributing to lower SO 2 prices for 2006 are: Below-cap SO 2 emissions output: The 2006 SO 2 emissions cap established by the EPA s Acid Rain Program was 9.5 million tons. Preliminary EPA data show power plant SO 2 emissions came in under the cap at 9.39 million tons which is down 8% compared with 2005 s SO 2 output of million tons. Surplus allowances: Of the 15.7 million SO 2 allowances available for 2006 compliance, 6.16 million allowances were carried over from previous years. Increased use of low-sulfur, Powder River Basin coal due to improved rail deliverability. Greater use of natural gas in running power plants due to lower relative costs compared to residual fuel oil. Increased hydro-electric and nuclear output. Regional factors: Increased use of scrubbers in NC and KY and the mothballing of the Mohave generating station in Nevada. Information is derived from EPA data, Cantor Fitzgerald data and Argus Air Daily. Updated April 26,
8 Emissions Market: Emission Allowance Prices Page 8 of 8 NO X Although the EPA administers the NO X trading program, allowance allocation is determined by state specifications and is generally based on the historical performance of the plant. As of 2007, the NO X trading program, called the NO X SIP Call, includes 22 states. The NO X compliance season runs from May 1st through September 30th, however NO X 2006 vintage trades take place throughout the 2006 calendar year. In calendar year 2006, NO X SIP Call Allowance prices peaked on January 27th at $2,766. Prices dropped to their calendar-year low of $711 on December 8th. The NO X compliance season opened on May 1st at $2,433/ton. NO X 2006 vintage closed the 2006 compliance season at approximately $700/ton. Factors contributing to lower NO X vintage prices for 2006 include: Below-cap NO X emissions output: Preliminary EPA data show total 2006 NO X emissions came in at 492,000 tons, down 7% compared with 530,000 tons in 2005 and below the 2006 cap of 520,957 tons. Surplus allowances: Generators currently have a bank of approximately 217,000 allowances, 30,000 of which are carried over from Pollution controls such as selective catalytic reduction (SCR) units outperforming expectations. Declining natural gas prices compared to 2005 prices. Information is derived from EPA data, Cantor Fitzgerald data and Argus Air Daily. Updated April 26,
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