# 1 

# ATTACHMENT 1 TO DECLARATION OF SAM NAPOLITANO

Clean Air Interstate Rule, Acid Rain Program, and Former NOx Budget

Trading Program 2010 Progress Report

# Clean Air Interstate Rule, Acid Rain Program, and Former NOx Budget Trading Program 2010 Progress Report | Progress Reports | Clean Air Markets | Air & Radiation | US EPA

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x 

# Budget

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x 

# Emissions, Compliance, and Market Analyses Report 

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# Clean Air Interstate Rule, Acid Rain Program, and Former NO

x 

# Budget Trading Program 2010 Progress Report

SO 2 

# and NO

x 

# Emissions, Compliance, and Market Analyses

Report

CAIR Litigation and the Cross-State Air Pollution Rule | CAIR, ARP, and NBP Affected States and Units |

Emission Reductions | CAIR and ARP Program Compliance | Controls and Monitoring | Market Activity

The Clean Air Interstate Rule (CAIR) and the Acid Rain Program (ARP) are both cap and trade programs

designed to reduce emissions of sulfur dioxide (SO 2 

# ) and nitrogen oxides (NO

x 

# ) from power plants. On July

6, 2011, EPA finalized the Cross-State Air Pollution Rule (CSAPR) , which will replace CAIR starting in 2012.

The CSAPR will require 27 states in the eastern half of the U.S. to improve significantly air quality by

reducing power plant emissions of SO 2 

# and NO

x 

# that cross state lines and contribute to smog (ground-level

ozone) and soot (fine particle pollution) in other states. The first phase of compliance begins January 1,

2012 for SO 2 

# and annual NO

x 

# reductions and May 1, 2012 for ozone season NO

x 

# reductions. Additional SO 2



# reductions are required by sixteen Group 1 states in 2014 to eliminate their contribution to downwind air

quality problems.

CAIR, which will be implemented through 2011, also addresses regional interstate transport of ozone and

fine particle (PM 2.5 

# ) pollution. CAIR requires certain eastern states to limit annual emissions of NO

x 

# and SO 2 

# , which contribute to the

formation of ozone and PM 2.5 

# . It also requires certain states to limit ozone season NO

x 

# emissions, which contribute to the formation of

smog during the summer ozone season (May to September). CAIR includes three separate cap and trade programs to achieve the required

reductions: the CAIR NO

x 

# ozone season trading program, the CAIR NO

x 

# annual trading program, and the CAIR SO 2 

# annual trading

program. The CAIR NO

x 

# ozone season and annual programs began in 2009, while the CAIR SO 2 

# annual program began in 2010. All three

programs will be implemented through the 2011 compliance periods. The CSAPR will replace CAIR starting in 2012. The reduction in ozone

and PM 2.5 

# formation resulting from implementation of CAIR provides health benefits as well as improved visibility in national parks and

improvements in freshwater aquatic ecosystems in the eastern U.S.

The ARP, established under Title IV of the 1990 Clean Air Act (CAA) Amendments, requires major emission reductions of SO 2 

# and NO

x 

# , the

primary precursors of acid rain, from the power sector. The SO 2 

# program sets a permanent cap on the total amount of SO 2 

# that may be

emitted by electric generating units (EGUs) in the contiguous United States. The program is phased in, with the final 2010 SO 2 

# cap set at

8.95 million tons, a level of about one-half of the emissions from the power sector in 1980. NO

x 

# reductions under the ARP are achieved

through a program that applies to a subset of coal-fired EGUs and is closer to a traditional, rate-based regulatory system. Since the

program began in 1995, the ARP has achieved significant emission reductions.

The NO

x 

# Budget Trading Program (NBP) operated from 2003 to 2008. The NBP was a cap and trade

program that required NO

x 

# emission reductions from power plants and industrial units in the eastern U.S.

during the summer months.

Figure 1 contains important milestones for CAIR, ARP, CSAPR, and the former NBP.



# Figure 1: History of CAIR, ARP, CSAPR, and Former NBP

Source: EPA, 2011



# For the first time, EPA is combining emissions and compliance data for both CAIR and the ARP into one report to more holistically show Air & Radiation

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# Clean Air Interstate Rule, Acid Rain Program, and Former NOx Budget Trading Program 2010 Progress Report | Progress Reports | Clean Air Markets | Air & Radiation | US EPA

http://www.epa.gov/airmarkets/progress/ARPCAIR10_01.html [10/6/2011 11:36:32 AM] reductions in power sector emissions of SO 2 

# and NO

x 

# and the collective effect of these regional programs on human health and the

environment. Over the next several months, EPA will release a series of reports summarizing progress in 2010 under both CAIR and the

ARP. This first report presents 2010 data on combined emission reductions and compliance results for CAIR and the ARP. This report also

presents some historic NBP emissions data and evaluates shared progress under these programs in 2010 by analyzing emission reductions

and market activity. A forthcoming report will compare changes in emissions to changes in a variety of human health and environmental

indicators. For more information on the CSAPR, please visit the CSAPR website . For more information on CAIR, please visit the CAIR

website . For more information on the ARP, please visit the ARP website . For more information on the NBP, please visit the NO

x 

# Budget

Trading Program/NO

x 

# SIP Call website

.

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# CAIR Litigation and the Cross-State Air Pollution Rule

CAIR was finalized in 2005. However, in July 2008, the U.S. Court of Appeals for the D.C. Circuit granted several petitions for review of

CAIR, finding significant flaws in the rule. Subsequently, in December 2008, the court issued a ruling to keep CAIR and the CAIR Federal

Implementation Plans (FIPs) — including the CAIR trading programs — in place temporarily until EPA issues new rules to replace the CAIR

and the CAIR FIPs.

On July 6, 2011, EPA finalized the Cross-State Air Pollution Rule (CSAPR) to replace CAIR. This rule responds to the court’s concerns and

fulfills the “good neighbor” provision of the Clean Air Act by addressing the problem of air pollution that is transported across state

boundaries.

In a separate but related regulatory action, EPA also issued a supplemental notice of proposed rulemaking (SNPR) to require six states —

Iowa, Kansas, Michigan, Missouri, Oklahoma, and Wisconsin — to make summertime NO

x 

# reductions under the CSAPR ozone-season

control program. Finalizing this supplemental proposal would bring the total number of covered states under the CSAPR to 28.

Visit the CSAPR website for more information.

Top of page



# CAIR, ARP, and NBP Affected States and Units

Affected States

The ARP is a nationwide program affecting large fossil fuel-fired power plants across the country. CAIR covers 27 eastern states and the

District of Columbia (D.C.) and requires reductions in annual emissions of SO 2 

# and NO

x 

# from 24 states and D.C. (to achieve improvements

in fine particle pollution in downwind areas) and emission reductions of NO

x 

# during the ozone season from 25 states and D.C. (to achieve

improvements in ozone pollution in downwind areas). The former NBP affected 20 eastern states and D.C. State coverage for CAIR, ARP,

and NBP is shown in Figure 2.



# Figure 2: CAIR, ARP, and NBP States

Note: In November 2009, EPA finalized a rule staying the requirements of CAIR for Minnesota. Minnesota is therefore not currently included in the CAIR annual

SO 2 

# and NO

x 

# programs.

Source: EPA, 2011



# Affected Units

The CAIR SO 2 

# and NO

x 

# annual programs generally apply to large EGUs — boilers, turbines, and combined cycle units that primarily burn

# Clean Air Interstate Rule, Acid Rain Program, and Former NOx Budget Trading Program 2010 Progress Report | Progress Reports | Clean Air Markets | Air & Radiation | US EPA

http://www.epa.gov/airmarkets/progress/ARPCAIR10_01.html [10/6/2011 11:36:32 AM] fossil fuels to generate electricity for sale. The CAIR NO

x 

# ozone season program includes EGUs as well as, in some states, large industrial

units that produce electricity or steam primarily for internal use and that have been carried over from the NBP. Examples of these units are

boilers and turbines at heavy manufacturing facilities, such as paper mills, petroleum refineries, and iron and steel production facilities.

These units also include steam plants at institutional settings, such as large universities or hospitals.

In 2010, there were 3,349 affected EGUs at 955 facilities in the CAIR SO 2 

# and NO

x 

# annual programs and 3,309 EGUs and industrial facility

units at 953 facilities in the CAIR NO

x 

# ozone season program (see Table 1 , below). The variation in the number of units covered under the

programs is due to the difference in states that are included in each program (see Figure 2, above ). The CAIR programs cover a range of

unit types, including units that operate year round to provide baseload power to the electric grid as well as units that provide power on

peak demand days only and may not operate at all during some years.

The SO 2 

# requirements under the ARP apply to the 3,613 large (greater than 25 megawatts) fossil fuel-fired combustion units that serve a

generator that provides electricity for sale at 1,241 facilities across the country. The vast majority of ARP SO 2 

# emissions result from coalfired EGUs, although the program also applies to oil and gas units. Of the 3,349 units in the CAIR SO 2 

# program, 2,626 (78 percent) were

also covered by the ARP in 2010. The other units are largely fossil fuel generation units that entered SO 2 

# control under the broader

applicability requirements of CAIR.

The ARP also requires NO

x 

# emission reductions for older, large coal-fired EGUs by limiting their NO

x 

# emission rate (expressed in

lb/mmBtu). The goal of the NO

x 

# program is to limit NO

x 

# emission levels from the affected coal-fired boilers so that their emissions are at

least two million tons less than the projected level for the year 2000 without implementation of Title IV. In 2010, 956 units at 379 facilities

were subject to the ARP NO

x 

# program.



# Table 1: Affected Units in CAIR and ARP, 2010

Fuel ARP SO 2 

# Program ARP NO

x 

# Program CAIR NO

x 

# Ozone

Season Program CAIR NO

x 

# and SO 2



# Annual Programs

Coal EGUs 1,055 944 875 922

Gas EGUs 2,333 10 1,657 1,945

Oil EGUs 200 0 555 463

Industrial Units 0 0 203 0

Unclassified EGUs 9 0 1 4

Other Fuel EGUs 16 2 18 15

Total Units 3,613 956 3,309 3,349

Notes:

“Unclassified” units have not submitted a fuel type in their monitoring plan and did not report emissions.

“Other” fuel refers to units that burn waste, wood, petroleum coke, tire-derived fuel, etc.

Source: EPA, 2011

Top of page



# Emission Reductions

Milestone Years for Measuring Progress under CAIR and ARP

1980: The Clean Air Act specified that annual SO 2 

# emissions be cut to 10 million tons below the

1980 level

1990: Baseline emission levels for the ARP

1995: First year of the ARP (Phase 1)

2000: Phase 2 of the ARP

2005: Baseline emission levels for CAIR

2008: “Training year” for CAIR NO

x 

# monitoring. Units participating in the two CAIR NO

x 

# trading

programs were required to monitor and report their emissions, but were not required to hold

allowances for compliance

2009: First year of CAIR NO

x 

# annual and CAIR NO

x 

# ozone season programs (Phase 1). “Training

year” for CAIR SO 2 

# monitoring

2010: First year of CAIR SO 2 

# annual program (Phase 1)



# Overall Trends

Table 2 , below, shows a large reduction in annual SO 2 

# and NO

x 

# emissions from CAIR and ARP sources between 2005 and 2010. Tons of

SO 2 

# emitted fell 49 percent from the 2005 level, and annual NO

x 

# emissions dropped 42 percent. During this same period, ozone season

NO

x 

# emissions from CAIR sources alone decreased by approximately 27 percent. These reductions occurred while electricity demand

(measured as heat input) remained relatively stable, indicating that the reduction in emissions was not driven by decreased electric

generation. Instead, there was a significant drop in emission rate for sources in all three programs: 49 percent for SO 2 

# sources, 42 percent

for annual NO

x 

# sources, and 25 percent for ozone season NO

x 

# sources. A drop in emission rate represents an overall increase in the

environmental efficiency of these sources as power generators installed controls, ran their NO

x 

# controls year round, switched to different

fuels, or otherwise cut their SO 2 

# and NO

x 

# emissions while meeting relatively steady demand for power. Most of the reductions since 2005

are from early reduction incentives and stricter emission limits under CAIR.

Between 2009 and 2010, CAIR and ARP sources continued to reduce their SO 2 

# emissions and emission rate. These reductions occurred

despite an 8 percent increase in demand for electricity. Annual NO

x 

# emissions from CAIR and ARP sources, however, rose slightly (4

percent) and in line with a similar increase in heat input (6 percent) during this time. Finally, CAIR sources’ ozone season NO emissions

# Clean Air Interstate Rule, Acid Rain Program, and Former NOx Budget Trading Program 2010 Progress Report | Progress Reports | Clean Air Markets | Air & Radiation | US EPA

http://www.epa.gov/airmarkets/progress/ARPCAIR10_01.html [10/6/2011 11:36:32 AM] x



# increased considerably (20 percent) as demand for electricity at these facilities rose substantially (more than 16 percent). Despite these

increases in NO

x 

# emissions as sources ran their controls less often, facilities were still below both the CAIR NO

x 

# ozone season and CAIR

NO

x 

# annual budgets for the year.

Visit EPA’s Quarterly Emissions Tracking site for the most up-to-date emissions and control data for sources in the ARP.



# Table 2: Comparison of Emissions, Emission Rates, and Heat Input for CAIR, ARP, and NBP Sources, 2000–

2010

CAIR and ARP Annual SO 2 

# Trends

SO 2 

# Emissions (thousand tons) SO 2 

# Rate (lb/mmBtu) Heat Input (billion mmBtu)

Primary Fuel 2000 2005 2008 2009 2010 2000 2005 2008 2009 2010 2000 2005 2008 2009 2010

Coal 10,707 9,835 7,514 5,653 5,089 1.04 0.95 0.74 0.63 0.53 20.67 20.77 20.25 18.02 19.29

Gas 28 36 10 6 7 0.02 0.01 0.00 0.00 0.00 3.71 5.35 6.22 6.50 7.19

Oil 464 347 83 54 44 0.76 0.71 0.35 0.29 0.21 1.22 0.98 0.47 0.37 0.41

Other 1 4 9 8 26 0.23 0.27 0.28 0.27 0.53 0.01 0.03 0.06 0.06 0.10

Total 11,201 10,223 7,616 5,722 5,166 0.88 0.75 0.56 0.46 0.38 25.61 27.13 27.00 24.95 26.99



# CAIR and ARP Annual NO

x 

# Trends

NO

x 

# Emissions (thousand tons) NO

x 

# Rate (lb/mmBtu) Heat Input (billion mmBtu)

Primary Fuel 2000 2005 2008 2009 2010 2000 2005 2008 2009 2010 2000 2005 2008 2009 2010

Coal 4,586 3,356 2,816 1,847 1,922 0.44 0.32 0.28 0.20 0.20 20.67 20.77 20.25 18.27 19.29

Gas 321 142 130 133 139 0.17 0.05 0.04 0.04 0.04 3.71 5.35 6.22 6.71 7.19

Oil 195 129 46 34 34 0.32 0.26 0.19 0.18 0.17 1.22 0.98 0.47 0.38 0.41

Other 2 6 5 5 7 0.26 0.42 0.16 0.12 0.13 0.01 0.03 0.06 0.09 0.10

Total 5,104 3,633 2,996 2,020 2,102 0.40 0.27 0.22 0.16 0.16 25.61 27.13 27.00 25.45 26.99



# NBP Ozone Season NO

x 

# Trends

NO

x 

# Emissions (thousand tons) NO

x 

# Rate (lb/mmBtu) Heat Input (billion mmBtu)

Primary Fuel 2000 2005 2008 2000 2005 2008 2000 2005 2008

Coal 1,111 494 456 0.46 0.19 0.19 4.85 5.10 4.93

Gas 15 23 17 0.08 0.05 0.04 0.37 0.85 0.85

Oil 34 32 9 0.21 0.21 0.14 0.32 0.31 0.13

Other 0 0 0 0.74 0.50 0.13 0.00 0.00 0.01

Total 1,160 549 482 0.42 0.18 0.16 5.54 6.27 5.91



# CAIR Ozone Season NO

x 

# Trends

NO

x 

# Emissions (thousand tons) NO

x 

# Rate (lb/mmBtu) Heat Input (billion mmBtu)

Primary Fuel 2000 2005 2008 2009 2010 2000 2005 2008 2009 2010 2000 2005 2008 2009 2010

Coal 1,398 695 625 442 527 0.45 0.22 0.20 0.17 0.18 6.19 6.31 6.14 5.21 5.85

Gas 62 43 34 33 42 0.15 0.06 0.05 0.04 0.04 0.84 1.47 1.40 1.53 1.96

Oil 83 72 28 19 22 0.29 0.27 0.20 0.18 0.16 0.57 0.53 0.28 0.21 0.27

Other 1 2 2 2 2 0.15 0.17 0.14 0.14 0.12 0.02 0.02 0.03 0.02 0.04

Total 1,545 812 689 495 594 0.41 0.20 0.18 0.14 0.15 7.62 8.33 7.85 6.97 8.12

Notes:

The data shown here for the annual programs and the NBP reflect totals for those facilities required to comply with each program in each respective year. This

means that CAIR NO

x 

# annual program facilities are not included in the annual NO

x 

# data for 2005 or 2008, and CAIR SO 2 

# annual program facilities are not

included in the annual SO 2 

# data for 2005, 2008, or 2009.

The CAIR NO

x 

# ozone season table includes emissions and heat input data for 2005 that were reported under other programs. For facilities that were not

covered by another program and did not report 2005 emissions, their reported emissions for 2008 were substituted.

2008 was a “training year” for facilities covered by the CAIR NO

x 

# annual and ozone season programs.

2009 was a monitoring and reporting “training year” for facilities covered by the CAIR SO 2 

# annual program.

Fuel type represents primary fuel type; units might combust more than one fuel.

Totals may not reflect the sum of individual rows due to rounding.

Each year’s total emission rate does not equal the arithmetic mean of the four fuel-specific rates, as each facility influences the annual emission rate in

proportion to its heat input, and heat input is unevenly distributed across the fuel categories.

EPA data in these tables and used elsewhere in this report are current as of July 2011, and may differ from past or future reports as a result of resubmissions

by sources and ongoing data quality assurance activities.

Source: EPA, 2011



# SO 2 

# Emission Reductions

# Clean Air Interstate Rule, Acid Rain Program, and Former NOx Budget Trading Program 2010 Progress Report | Progress Reports | Clean Air Markets | Air & Radiation | US EPA

http://www.epa.gov/airmarkets/progress/ARPCAIR10_01.html [10/6/2011 11:36:32 AM] Figure 3 , below, shows that the CAIR SO 2 

# program continues and complements the ARP’s history of SO 2 

# emission reductions. In 2010, the

first year of operation of the CAIR SO 2 

# trading program, sources in both the CAIR SO 2 

# annual program and the ARP together reduced SO 2



# emissions by over 10 million tons (67 percent) from 1990 levels (before implementation of the ARP), 6 million tons (54 percent) from 2000

levels (ARP Phase 2), and 5 million tons (49 percent) from 2005 levels (before implementation of CAIR). All ARP and CAIR sources together

emitted a total of 5.2 million tons of SO 2 

# in 2010, well below the ARP’s statutory annual cap of 8.95 million tons.

Annual SO 2 

# emissions from sources in the CAIR SO 2 

# program alone fell from 9 million tons in 2005 to 4.4 million tons in 2010, a 51

percent reduction. Between 2009 and 2010, SO 2 

# emissions fell 123,000 tons, or 6 percent. However, the 2010 emissions total is higher

than the CAIR SO 2 

# program’s state budget total of 3.6 million tons, indicating that affected sources used banked allowances carried over

from the ARP for compliance with CAIR (see Table 3 , below).

ARP units alone emitted 5.1 million tons of SO 2 

# in 2010, meaning that ARP sources reduced emissions by 10.6 million tons (67 percent)

from 1990 levels and 12.1 milllion tons (70 percent) from 1980 levels.



# Figure 3: SO 2 

# Emissions from CAIR SO 2 

# Annual Program and ARP Sources, 1980–2010

Note: For CAIR units not in the ARP, the 2009 annual SO 2 

# emissions were applied retroactively for each pre-CAIR year following the year in which the unit began

operating.

Source: EPA, 2011



# The states with the highest emitting sources in 1990 have generally seen the greatest SO 2 

# reductions under the ARP, and this trend

continues under CAIR (see Figure 4 , below). Most of these states are upwind of the areas the ARP and CAIR were designed to protect, and

reductions have resulted in important environmental and health benefits over a large region.

From 1990 to 2010, annual SO 2 

# emissions in the nationwide ARP dropped in 40 states and D.C. by a total of approximately 10.5 million

tons. In contrast, annual SO 2 

# emissions increased by a total of only 30,700 tons in eight states (Idaho, Louisiana, Montana, North Dakota,

Nebraska, Oregon, Rhode Island, and Vermont) from 1990 to 2010.

Between 2005 and 2010, annual SO 2 

# emissions fell in all 27 states in the CAIR region with the exception of Arkansas and D.C., which

increased emissions by a total of only 933 tons. Sixteen states and D.C. exceeded their state SO 2 

# emission budgets.



# Figure 4: State-by-State Annual SO 2 

# Emission Levels for CAIR and ARP Sources, 1990–2010

# Clean Air Interstate Rule, Acid Rain Program, and Former NOx Budget Trading Program 2010 Progress Report | Progress Reports | Clean Air Markets | Air & Radiation | US EPA

http://www.epa.gov/airmarkets/progress/ARPCAIR10_01.html [10/6/2011 11:36:32 AM] Note: State-level data shown in this map are available for download.

Source: EPA, 2011



# Thirty-five ARP units installed SO 2 

# controls in 2010, reducing their collective SO 2 

# emission rate from 1.15 lb/mmBtu in January to 0.10

lb/mmBtu in December. The remaining sources in the ARP reported a steady annual SO 2 

# rate of about 0.41 lb/mmBtu (see Figure 5

, below). Had these newly-controlled units maintained their collective annual 2009 emission rate of 1.20 lb/mmBtu through 2010, their

estimated emissions would have remained around a half million tons. In actuality, the 35 units emitted 64 percent less SO 2 

# in 2010 than in

2009 by adding scrubbers, contributing about half of the total program-wide reduction of 600,000 tons between 2009 and 2010. Because

the new controls were installed at different times throughout 2010, the annual reduction reflects only partial operation, and the overall

benefits of the new systems will be even greater in 2011.



# Figure 5: Monthly SO 2 

# Emission Rates, 2010

Source: EPA, 2011



# NO

x 

# Emission Reductions

Ozone Season NO

x 

# Reductions

Figure 6 , below, shows ozone season NO

x 

# emissions from 1990 to the present for CAIR and NBP sources. In 2010, the second year of the

CAIR NO

x 

# ozone season program, sources from both CAIR and the former NBP, together with a small number of sources that were

previously in the NBP but did not enter CAIR, reduced their overall NO

x 

# emissions from 816,000 tons in 2005 (before implementation of

CAIR) to 599,000 tons in 2010, a decrease of 27 percent. NO

x 

# emissions were nearly 1.5 million tons lower (71 percent) than in 1990 and

860,000 tons lower (59 percent) than in 2000 (before implementation of the NBP).

# Clean Air Interstate Rule, Acid Rain Program, and Former NOx Budget Trading Program 2010 Progress Report | Progress Reports | Clean Air Markets | Air & Radiation | US EPA

http://www.epa.gov/airmarkets/progress/ARPCAIR10_01.html [10/6/2011 11:36:32 AM] Between 2005 and 2010, ozone season NO

x 

# emissions from sources in the CAIR program alone have fallen 211,000 tons, a decrease of 22

percent. From 2009 to 2010, however, ozone season NO

x 

# emissions from sources in the CAIR NO

x 

# ozone season program increased by

99,000 tons (20 percent) as sources operated controls less often and electricity demand rose. Despite the year-over-year increase, ozone

season NO

x 

# emissions totaled 594,000 tons in 2010, 5 percent below the 2010 regional emission budget of 624,698 tons.



# Figure 6: Ozone Season NO

x 

# Emissions from CAIR and NBP Sources, 1990–2010

Note: For CAIR units not in the NBP, the 2008 NO

x 

# emissions were applied retroactively to 1990 and 2000 if the unit operated in the previous year’s ozone

season.

Source: EPA, 2011



# The average NO

x 

# emission rate is a key measure of program effectiveness. While emissions may vary year to year due to changes in

electricity demand the average ozone season NO

x 

# emission rate has fallen every year since 2004 — except 2010. The driver of the increase

in rate was coal-fired units with add-on controls. The NO

x 

# emission rate at these units, which are historically responsible for the deepest

reductions, increased as a group over 14 percent from 2009 to 2010.

Ozone season NO

x 

# mass emissions rose about 99,000 tons between 2009 and 2010. Nearly a third of the increase (28,192 tons) resulted

from fifty coal-fired units with add-on controls that posted significantly poorer performance in 2010. These fifty units “dialed back” control

removal efficiency or even turned installed controls off. At 24 units, the 2010 NO

x 

# emission rate was double that of 2009. In an emissions

trading program, operators of plants are assumed to optimize operations by balancing the costs of fuel, allowances, and running controls.

For example, the relatively low cost of gas drove the 35 percent increase in gas-fired generation in 2010. Similarly, the drop in allowance

prices could lead to a higher NO

x 

# emission rate. EPA expects the average NO

x 

# emission rate to continue to improve in future years under

the regulatory certainty provided by CSAPR. The higher NO

x 

# allowance prices that should exist in 2012 under CSAPR would provide

incentive for sources to improve the effectiveness of existing pollution controls.

Between 2005 and 2010, ozone season NO

x 

# emissions from CAIR and former NBP sources fell in every state participating in the CAIR NO

x



# ozone season program except Pennsylvania, Arkansas, Kentucky, and D.C. (see Figure 7 , below), where emissions increased by a total of

15,000 tons. In the 2010 ozone season, the total emissions from participating sources were about 31,000 tons below the regional emission

budget. Sixteen states had emissions below their allowance budgets, collectively by about 80,000 tons. Another ten states exceeded their

2010 budgets by a total of about 49,000 tons, indicating that, on an aggregate basis, sources within those states covered a portion of their

emissions with allowances banked from earlier years, transferred from an out-of-state account, or purchased from the market.



# Figure 7: State-by-State Ozone Season NO

x 

# Emission Levels from CAIR Sources, 2000–2010

# Clean Air Interstate Rule, Acid Rain Program, and Former NOx Budget Trading Program 2010 Progress Report | Progress Reports | Clean Air Markets | Air & Radiation | US EPA

http://www.epa.gov/airmarkets/progress/ARPCAIR10_01.html [10/6/2011 11:36:32 AM] Notes:

State-level data shown in this map is available for download.

The 2000 and 2005 ozone season values reflect data that were reported under other programs (ARP and NBP). For facilities that were not covered by another

program and did not report 2000 or 2005 emissions, their reported emissions for the earliest subsequent year (usually the 2008 training year) were substituted.

Source: EPA, 2011



# In addition to the CAIR NO

x 

# ozone season program and the former NBP, prior programs such as the Ozone Transport Commission’s (OTC)

NO

x 

# Budget Program and current regional and state NO

x 

# emission control programs have also contributed significantly to the ozone season

NO

x 

# reductions achieved by sources in 2010.



# High Electric Demand Days

Ozone season demand for electricity is driven by economic conditions and weather. Figure 8 , below, compares 2009 and 2010 ozone

season daily NO

x 

# emissions and generation (as measured by gross megawatt hours), and highlights the ten days of each year's peak

generation. Comparing the ten peak generation days in 2009 to 2010, generation increased 14 percent, NO

x 

# emissions grew

proportionately (17 percent), while the NO

x 

# emission rate increased by less than two percent. The fact that the NO

x 

# rate during the ten

days of highest electric demand remained below the ozone season average implies that the increased demand did not result in less

efficient, higher-emitting units being called into service, as had historically been the case.



# Figure 8: Ozone Season Daily NO

x 

# Emissions and Generation

# Clean Air Interstate Rule, Acid Rain Program, and Former NOx Budget Trading Program 2010 Progress Report | Progress Reports | Clean Air Markets | Air & Radiation | US EPA

http://www.epa.gov/airmarkets/progress/ARPCAIR10_01.html [10/6/2011 11:36:32 AM] Source: EPA, 2011



# Annual NO

x 

# Reductions

Figure 9 , below, shows that from 1990 to 2010, annual NO

x 

# emissions from CAIR and ARP units together dropped by about 4.3 million

tons to 2.1 million tons, a decrease of 67 percent. In 2010, the second year of the CAIR NO

x 

# annual program, NO

x 

# emissions from all ARP

and CAIR units were 1.5 million tons lower (42 percent) than in 2005 and 3 million tons lower (59 percent) than in 2000.

Emissions from CAIR NO

x 

# annual program sources alone were 1.43 million tons in 2010, 73,000 tons (5 percent) below the 2010 CAIR NO

x



# annual program’s regional budget of 1.5 million tons. Annual NO

x 

# emissions were 1.2 million tons lower (47 percent) than in 2005, but

# Clean Air Interstate Rule, Acid Rain Program, and Former NOx Budget Trading Program 2010 Progress Report | Progress Reports | Clean Air Markets | Air & Radiation | US EPA

http://www.epa.gov/airmarkets/progress/ARPCAIR10_01.html [10/6/2011 11:36:32 AM] were 115,000 tons (9 percent) higher than in 2009. This recent increase was largely a result of sources not operating NO

x 

# controls as often

and increased demand for electricity.

ARP sources emitted 2.1 million tons of NO

x 

# in 2010. This level is 6 million tons less than the projected level in 2000 without the ARP, and

triple the Title IV NO

x 

# emission reduction objective.

Although the ARP and CAIR NO

x 

# programs were responsible for a large portion of these annual NO

x 

# reductions, other programs — such as

the NBP, the OTC NO

x 

# Budget Program, and other regional and state NO

x 

# emission control programs — also contributed significantly to the

annual NO

x 

# reductions achieved by sources in 2010.



# Figure 9: Annual NO

x 

# Emissions from CAIR and ARP Sources, 1990–2010

Note: For CAIR units not in the ARP in 1990, 2000, and 2005, the 2008 annual NO

x 

# emissions were applied retroactively for each pre-CAIR year following the

year in which the unit began operating.

Source: EPA, 2011



# Figure 10 , below, shows that, compared with 2005, before implementation of CAIR, sources in the CAIR NO

x 

# annual program continued to

reduce year-round emissions in 2010 as program participants operated NO

x 

# control devices on EGUs outside the summer months. From

2005 to 2010, NO

x 

# emissions from units in the CAIR NO

x 

# annual program and ARP fell 42 percent, while heat input remained stable, falling

less than one percent.



# Figure 10: Monthly Emissions and Heat Input from CAIR NO

x 

# Annual Program Sources, 2005 vs. 2010

Note: The CAIR NO

x 

# annual program had not begun in 2005, so the set of participating units from 2008 was used as the 2005 baseline in this figure. Facilities

that were not covered by the ARP did not report emissions in 2005. For these facilities, the earliest subsequent reported values, usually from the 2008 CAIR

training year, were substituted.

Source: EPA, 2011



# From 1990 to 2010, all states participating in the CAIR NO

x 

# annual program decreased their emissions, as indicated in Figure 11 , below.

Comparing 2005 to 2010, all states in the CAIR region emitted less NO

x 

# except Delaware and D.C., which increased their NO

x 

# emissions by

855 tons. The total NO

x 

# emissions from participating sources in 2010 were about 55,000 tons below the regional emission budget of

1,490,264 tons. Ten states and D.C. exceeded their 2010 budgets by a total of about 109,000 tons, indicating that, on an aggregate basis,

sources within those states covered a portion of their emissions with allowances banked from earlier years, transferred from an out-ofstate account, or purchased from the market.



# Figure 11: State-by-State Annual NO

x 

# Emission Levels for CAIR and ARP Sources, 1990–2010

# Clean Air Interstate Rule, Acid Rain Program, and Former NOx Budget Trading Program 2010 Progress Report | Progress Reports | Clean Air Markets | Air & Radiation | US EPA

http://www.epa.gov/airmarkets/progress/ARPCAIR10_01.html [10/6/2011 11:36:32 AM] Note: State-level data shown in this map is available for download.

Source: EPA, 2011

Top of page



# CAIR and ARP Program Compliance

SO 2 

# Programs

Because SO 2 

# allowances from the ARP are used by sources to comply with the CAIR SO 2 

# annual program, compliance results for both

programs are displayed together in this report. Table 3 , below, shows how ARP and CAIR allowances were used. All ARP and CAIR SO 2



# facilities were in compliance with both programs and held enough allowances to cover their SO 2 

# emissions.



# Table 3: CAIR and ARP SO 2 

# Allowance Reconciliation Summary, 2010

Total Allowances Held (1995–2010 Vintage) 21,505,185

Affected Facility Accounts: 14,599,394

Other (General and Non-Affected Facility Accounts): 6,905,791

Allowances Deducted for Acid Rain Compliance* 5,081,366

Penalty Allowance Deductions (2011 Vintage) 0

Banked Allowances (prior to CAIRSO 2 

# deductions) 16,423,819

Affected Facility Accounts: 9,518,028

Other (General and Non-Affected Facility Accounts): 6,905,791

Acid Rain Program Allowances Deducted for CAIR SO 2 

# Compliance 1,188,678

Banked Allowances 15,235,141

Affected Facility Accounts: 8,329,350

Other (General and Non-Affected Facility Accounts): 6,905,791

*Includes 6,111 allowances deducted from opt-ins for reduced utilization.



# Compliance Results

As of July 2, 2011, the reported 2010 SO 2 

# emissions by CAIR and ARP

sources totaled 5,166,487 tons. Because of variation in rounding

conventions, changes due to resubmissions by sources, and allowance

compliance issues at certain units, this number is lower than the sums of

emissions used for reconciliation purposes shown in Table 3 , above.

Therefore, the allowance totals deducted for actual emissions in Table 3

differ from the number of emissions shown elsewhere in this report.

CAIR and ARP SO 2 

# Programs

Reported emissions (tons): 5,166,487

Compliance issues, rounding, and report resubmission

adjustments (tons): –45,912

Emissions not covered by allowances (tons): 0

# Clean Air Interstate Rule, Acid Rain Program, and Former NOx Budget Trading Program 2010 Progress Report | Progress Reports | Clean Air Markets | Air & Radiation | US EPA

http://www.epa.gov/airmarkets/progress/ARPCAIR10_01.html [10/6/2011 11:36:32 AM] Additional vintage 2010 allowances deducted for CAIR: +1,143,358

Total allowances deducted for emissions (includes some 2 for

1 CAIR deductions: 6,263,933



# 2010 was the first year for compliance with the CAIR SO 2 

# program. Under this program, allowances are used to cover emissions based on

the vintage year of the allowances, with pre–2010 vintage allowances used at 1 allowance for 1 ton of SO 2 

# emissions, and 2010 vintage

allowances used at 2 allowances for 1 ton. For facilities covered by both CAIR and the ARP, reconciliation is a two-step process. First, ARP

deductions are made. Then, any additional deductions to comply with the CAIR SO 2 

# program are made. The additional deductions under

CAIR could be to cover the 2 for 1 use of 2010 allowances or to cover emissions for units that are subject to CAIR, but not the ARP.

In 2010, almost 22 million SO 2 

# allowances were available for compliance under both programs (9 million vintage 2010 and almost 13

million banked from prior years). Just over 5 million allowances were deducted for ARP compliance and an additional 1.2 million allowances

were deducted to complete reconciliation for CAIR. After reconciliation for both programs, over 15.2 million ARP SO 2 

# allowances were

banked and carried forward to the 2011 compliance year.

Top of page



# NO

x 

# Programs

CAIR NO

x 

# Compliance Results

Tables 4 and 5 , below, show how NO

x 

# allowances were used in 2010. All covered facilities were in compliance with the CAIR NO

x 

# annual

and ozone season programs and held enough allowances to cover their NO

x 

# emissions.



# Table 4: CAIR NO

x 

# Ozone Season Allowance Reconciliation Summary, 2010

Total Allowances Held (2003–2010 Vintage) 1,002,016

Affected Facility Accounts: 873,775

Other (General, State Holding and Non-Affected Facility Accounts): 128,241

Allowances Deducted for CAIR NO

x 

# Ozone Season Trading Program 587,127

Penalty Allowance Deductions (2011 Vintage) 0

Banked Allowances 414,889

Affected Facility Accounts: 286,648

Other (General, State Holding and Non-Affected Facility Accounts): 128,241



# Table 5: CAIR NO

x 

# Annual Allowance Reconciliation Summary, 2010

Total Allowances Held (2009–2010 Vintage) 1,823,717

Affected Facility Accounts: 1,723,440

Other (General, State Holding and Non-Affected Facility Accounts): 100,277

Allowances Deducted for CAIR NO

x 

# Annual Trading Program 1,420,621

Penalty Allowance Deductions (2011 Vintage) 0

Banked Allowances 403,096

Affected Facility Accounts: 302,819

Other (General, State Holding and Non-Affected Facility Accounts): 100,277



# Compliance Results

As of July 3, 2011, the reported 2010 ozone season NO

x 

# emissions by

CAIR sources totaled 593,669 tons, and annual emissions totaled

1,427,301 tons. Because of variation in rounding conventions, changes

due to resubmissions by sources, and allowance compliance issues at

certain units, these numbers are different from the sums of emissions

used for reconciliation purposes shown in Table 4 (ozone season

reconciliation) and Table 5 (annual reconciliation). Therefore, the

allowance totals deducted for actual emissions in Tables 4 and 5 differ

from the number of emissions shown elsewhere in this report.

CAIR NO

x 

# Ozone Season

Reported emissions (tons): 593,669

Compliance issues, rounding, and report resubmission

adjustments (tons): –6,542

Emissions not covered by allowances (tons): 0

Total allowances deducted for emissions: 587,127

CAIR NO

x 

# Annual Program

Reported emissions (tons): 1,427,301

Compliance issues, rounding, and report resubmission

adjustments (tons): -6,680

Emissions not covered by allowances (tons): 0

Total allowances deducted for emissions: 1,420,621

# Clean Air Interstate Rule, Acid Rain Program, and Former NOx Budget Trading Program 2010 Progress Report | Progress Reports | Clean Air Markets | Air & Radiation | US EPA

http://www.epa.gov/airmarkets/progress/ARPCAIR10_01.html [10/6/2011 11:36:32 AM] On May 1, 2009, the NBP transitioned to the CAIR NO

x 

# ozone season program and transferred a total of 275,367 allowances from the NBP

to the CAIR NO

x 

# ozone season program. By the end of the 2009 ozone season, 392,799 allowances were banked and available for program

compliance in 2010. Because NO

x 

# emissions in the 2010 ozone season were below the CAIR budget, sources were able to bank additional

allowances, leaving 414,889 allowances available for use in 2011.

Under the CAIR NO

x 

# annual program, 342,975 allowances were carried over from 2009. Because annual NO

x 

# emissions in 2010 were also

below the CAIR budget, after reconciliation, 403,096 allowances remained in the bank to be carried over into 2011.



# ARP NO

x 

# Compliance Results

The ARP NO

x 

# Program does not impose a cap on NO

x 

# emissions and does not rely on allowance trading. The program allows affected

sources to comply either by meeting a unit-specific emission rate or by including two or more units in an emission rate averaging plan.

These options provide affected sources with the flexibility to meet the NO

x 

# emission reduction requirements in a cost-effective manner. In

2010, all 956 units that were subject to the ARP NO

x 

# Program achieved compliance.

Top of page



# Controls and Monitoring

To meet the ARP and CAIR emission reduction targets, some sources opt to install control technologies. A wide set of controls are available

to help reduce emissions. The following is an analysis of controls on ARP and CAIR program coal-fired units and CAIR NO

x 

# program

combined cycle units in 2010.



# SO 2 

# Controls in 2010

The wide variety of SO 2 

# control options available to sources includes switching to low sulfur coal or employing various types of flue gas

desulfurization units (FGDs), such as fluidized bed limestone units. FGDs on coal-fired generators are the principal means of controlling

SO 2 

# . As discussed in detail above, 35 units in the ARP added new SO 2 

# controls in 2010. Sources added FGDs at 34 of the units in the CAIR

SO 2 

# annual program. Across both programs the share of generation, measured in megawatt hours (MWh), at controlled units was 60

percent of coal-fired generation in 2010 (see Table 6 , below).



# Table 6: SO 2 

# Controls in 2010 on Coal-Fired Units in the ARP and CAIR Annual SO 2 

# Program

SO 2 

# Control Type Number of Units Share of Units Share of MWh Generation

FGD 427 38% 59%

Other 44 4% 1%

Uncontrolled 643 58% 39%

Note: Due to rounding, percentages shown may not add up to 100%.

Source: EPA, 2011



# NO

x 

# Controls in 2010

Sources have a variety of options by which to reduce NO

x 

# emissions. New selective catalytic reduction units (SCRs), the most efficient NO

x



# controls, were installed at five generation units under the CAIR NO

x 

# ozone season program in 2010. Units with add-on controls — SCR or

selective non-catalytic reduction (SNCR) — accounted for nearly two-thirds of coal-fired generation (59 percent) and 80 percent of

generation at combined cycle units (gas- or oil-fired). Although 124 coal-fired units and 15 combined cycle units remain uncontrolled, they

represent only two percent of coal-fired generation and one percent of combined cycle generation under the CAIR NO

x 

# ozone season

program (see Table 7 , below).



# Table 7: NO

x 

# Controls in 2010 CAIR NO

x 

# Ozone Season Program

NO

x 

# Control Type Number of Coal-Fired Units Share of Coal-Fired

MWh Generation Number of Combined Cycle

Units (Gas- or Oil-Fired) Share of Combined Cycle

(Gas- or Oil-Fired)

MWh Generation

Combustion 446 37% 66 13%

Non-Controlled 124 2% 15 1%

Other Control 38 1% 91 6%

SCR 207 51% 317 80%

SNCR 127 8% 0 0%

Note: Due to rounding, percentages shown may not add up to 100%.

Source: EPA, 2011



# Seven sources in the CAIR NO

x 

# annual program installed add-on controls in 2010. The 347 coal-fired units with add-on controls (either

SCRs or SNCRs) generated 57 percent of annual generation, and the 379 combined cycle units with SCRs generated 75 percent of annual

generation (see Table 8 , below). Similar to the CAIR NO

x 

# ozone season program, uncontrolled units represent two percent of coal-fired

generation and one percent of combined cycle generation under the CAIR NO

x 

# annual program.



# Table 8: NO

x 

# Controls in 2010 CAIR NO

x 

# Annual Program

Share of Combined Cycle

# Clean Air Interstate Rule, Acid Rain Program, and Former NOx Budget Trading Program 2010 Progress Report | Progress Reports | Clean Air Markets | Air & Radiation | US EPA

http://www.epa.gov/airmarkets/progress/ARPCAIR10_01.html [10/6/2011 11:36:32 AM] NO

x 

# Control Type Number of Coal-Fired Units Share of Coal-Fired

MWh Generation Number of Combined Cycle

Units (Gas- or Oil-Fired) (Gas- or Oil-Fired)

MWh Generation

Combustion 436 38% 120 20%

Non-Controlled 99 2% 19 1%

Other Control 40 2% 88 4%

SCR 222 49% 379 75%

SNCR 125 8% 0 0%

Note: Due to rounding, percentages shown may not add up to 100%.

Source: EPA, 2011



# Continuous Emission Monitoring Systems

Accurate and consistent emissions monitoring is the foundation of a cap and trade system. EPA has developed detailed procedures (40 CFR

Part 75) to ensure that sources monitor and report emissions with a high degree of precision, accuracy, reliability, and consistency.

Sources use continuous emission monitoring systems (CEMS) or other approved methods. Part 75 requires sources to conduct stringent

quality assurance tests of their monitoring systems, such as daily and quarterly calibration tests and a semiannual or annual relative

accuracy test audit. These tests ensure that sources report accurate data and provide assurance to market participants that a ton of

emissions measured at one facility is equivalent to a ton measured at a different facility.

While many CAIR units with low levels of emissions did not have to use CEMS, the vast majority of NO

x 

# emissions — over 99 percent —

were measured by CEMS. Similarly, CEMS monitored over 99 percent of SO 2 

# emissions including 100 percent from coal-fired units and 18

percent from oil-fired units. Coal-fired units were required to use CEMS for NO

x 

# concentration and stack gas flow rate to calculate and

record their NO

x 

# mass emissions. Oil-fired and gas-fired units could use a NO

x 

# CEMS in conjunction with a fuel flow meter to determine

NO

x 

# mass emissions. Alternatively, for oil-fired and gas-fired units that either operated infrequently or had very low NO

x 

# emissions, Part

75 provided low-cost alternatives to conservatively estimate NO

x 

# mass emissions. The relatively low percentage for oil-fired units with

CEMS is consistent with the decline in oil-fired heat input, as most of these units were used infrequently and qualified for reduced

monitoring.

Top of page



# Market Activity

SO 2 

# Allowance Market in 2010

Over the first decade of the ARP, allowance prices were stable and significantly lower than projected. When CAIR was proposed in late

2003, allowance prices were influenced by the more stringent CAIR SO 2 

# budget and the new compliance deadlines. With the start of the

CAIR SO 2 

# program in 2010, the Acid Rain SO 2 

# market essentially has become the CAIR SO 2 

# market. See Table 9 , below, for a summary of

the 2010 SO 2 

# allowance market.



# Table 9: SO 2 

# Allowance Market in Brief (close of 2010)

Total Value of the SO 2 

# Allowance Market: $290 million

Average Nominal Price: $19 per ton

Total Allowance Volume (Allowable Emissions): 15,233,537

Note: Total value of allowance market is a snapshot based on the average nominal price as of December 2010 ($19/ton) and total allowance volume available for

2010 compliance.

Source: EPA, 2011 and CantorCO2e Market Price Index, 2011



# NO

x 

# Allowance Markets in 2010

The 2010 CAIR NO

x 

# ozone season allowance market continued its price decline from the previous year closing at the end of December at

$30 per ton (see Figure 12 ). The annual NO

x 

# allowance price, as reported by the CantorCO2e Market Price Index, climbed briefly to $716

early in 2010 and then declined to $325 per ton by the end of the year.



# Figure 12: NO

x 

# Annual and Ozone Season Allowance Spot Price (Prompt Vintage), January — December

2010

Note: Prompt vintage is the vintage for the current compliance year.

Source: EPA, 2011 and CantorCO2e Market Price Index, 2011

# Clean Air Interstate Rule, Acid Rain Program, and Former NOx Budget Trading Program 2010 Progress Report | Progress Reports | Clean Air Markets | Air & Radiation | US EPA

http://www.epa.gov/airmarkets/progress/ARPCAIR10_01.html [10/6/2011 11:36:32 AM] EPA Home Privacy and Security Notice Contact Us

http://www.epa.gov/airmarkets/progress/ARPCAIR10_01.html

Print As-Is

Last updated on Thursday, October 06, 2011 

# In 2010, the second year of the CAIR ozone season and annual NO

x 

# programs, CAIR sources emitted about 594,000 tons of NO

x 

# during the

ozone season (May through September), a 20 percent increase from 2009 levels, but still below the overall budget. CAIR sources emitted

about 31,000 tons less than their overall ozone season budget, resulting in about 415,000 banked allowances. Not surprisingly, the

downward tendency of ozone season allowance prices continued through most of 2010. Emissions of CAIR annual NO

x 

# were 1.4 million

tons, about 82,000 tons less than the overall budget. The CAIR annual NO

x 

# bank grew to more than 400,000 allowances.

Generally, sources in a cap and trade program may consider several emission reduction alternatives and are allowed to trade allowances as

part of their compliance strategies. By allowing trades, the overall market can achieve emission targets at a lower cost than through a

command and control program because abatement costs are not the same for all sources. A market for emission allowances will emerge,

and the allowance price will reflect the marginal cost of emission reductions. Emission control decisions will be made based on the cost of

control options relative to the market price of allowances. The allowance price motivates those who have relatively low cost opportunities

for emission reductions to make those investments and then sell their surplus allowances to those with higher marginal abatement costs.

Looking at the CAIR NO

x 

# ozone season allowance market, it has been EPA’s expectation that the CAIR annual NO

x 

# cap would be the

binding constraint and absorb most of the capital costs of controls (i.e., SCRs), while the NO

x 

# ozone season allowance prices would

primarily be driven by operating costs. As expected, the current CAIR NO

x 

# allowance prices are below the total expected control cost.

However, in the middle of 2010, CAIR annual NO

x 

# allowance prices dipped below $500 per ton — the variable SCR cost and theoretical

floor price — and remained there through the rest of the year.



# Transaction Types and Volumes

Allowance transfer activity includes two types of transfers: EPA transfers to accounts and private transactions. EPA transfers to accounts

include the initial allocation of allowances by states or EPA, as well as transfers into accounts related to special set-asides. This category

does not include transfers due to allowance retirements. Private transactions include all transfers initiated by authorized account

representatives for any compliance or general account purposes.

To help better understand the trends in market performance and transfer history, EPA classifies private transfers of allowance transactions

into two categories:

Transfers between separate and distinct economic entities, which may include companies with contractual relationships such as

power purchase agreements, but excludes parent-subsidiary types of relationships. These transfers are categorized broadly as

“economically significant trades.”

Transfers within a company or between related entities (e.g., holding company transfers between a unit compliance account and

any account held by a company with an ownership interest in the unit).

While all transactions are important to proper market operation, EPA follows trends in the economically significant transaction category

with particular interest because these transactions represent an actual exchange of assets between unaffiliated participants. In 2010, about

a third of each program’s traded allowances were exchanged between unrelated parties, often with a broker facilitating the trade (see

Table 10 , below).



# Table 10: 2010 Allowance Transfers under CAIR and ARP

Program Transfer Type Number of

Allowances Transferred Share of

Program Allowances Transferred

CAIR NO

x 

# Ozone Season Distinct Organizations 132,854 36%

Related Organizations 237,151 64%

CAIR NO

x 

# Annual Distinct Organizations 344,758 39%

Related Organizations 540,267 61%

ARP and CAIR SO 2 

# Annual Distinct Organizations 3,009,858 33%

Related Organizations 6,056,910 66%

Note: Due to rounding, percentages shown may not add up to 100%.

Source: EPA, 2011



# Brokers play an important role in the emissions allowance markets. They primarily facilitate and conduct trades between willing buyers and

sellers, undertaking the direct costs of identifying trading partners and transacting sales at a price acceptable to both parties. In the

allowance trading market, the fees charged by brokerage firms are often considered to be transaction costs. These costs associated with

buying and selling allowances are generally low.

Top of page

# 1 

# ATTACHMENT 2 TO DECLARATION OF SAM NAPOLITANO

Garland Power & Light Activates Two Generation Units for ERCOT

Garland, TX, August 23, 2011

# Garland Power & Light Activates Two Generation Units

for ERCOT

Garland, TX, August 23, 2011 – Garland Power & Light (GP&L) has activated Spencer Units

#4 and #5 and officially released them to ERCOT to help reduce the risk of rotating outages on

the electric grid in Texas.

Around-the-clock efforts returned the gas-fired units to service from their mothballed state. Unit

#5 was turned over to ERCOT at midnight Sunday for Monday operation. Unit #4 was turned

over at midnight Monday for Tuesday operation. If needed, ERCOT can call on these units to

provide power to the grid to avoid emergencies. They will not displace units that were already

on-line and bidding into the market.

"The state continues to experience extremely high temperatures and the demand for power

remains high. We're pleased that our units are now available as a resource for ERCOT," said

GP&L's Electric Utility Director Ray Schwertner.

The units were originally targeted for return to service this Friday, but GP&L made these units

available sooner. "It's a tribute to our dedicated and highly skilled employees that we already

have these units on-line," said Schwertner.

As the units came on-line, ERCOT CEO Trip Dogg ett expressed appreciation to Schwertner for

GP&L's efforts in bringing the units back earlier than expected.

The Spencer units are located in Denton, Texas, and the power they generate will support load

in the North Texas region. Each of the units has a 61 megawatt (MW) capacity.

Background reference: http://www.ercot.com/news/press_releases/show/424

For more information, contact:

Elizabeth Kimbrough

Electric Marketing Manager

Garland Power & Light

972-205-2364

ekimbrough@garlandpower-light.org 

# Welcome To Garland Power & Light http://www.garlandpower-light.org/news/2011UnitActivation.html

1 of 1 9/12/2011 2:58 PM

# 1 

# ATTACHMENT 3 TO DECLARATION OF SAM NAPOLITANO

Report on the Capacity, Demand, and Reserves in the ERCOT Region, May

2011 (June 9, 2011 Revision 2)ReportontheCapacityDemandandReservesCapacity,,ReservesintheERCOTRegionMay2011(June9,2011Revision2)TabNotesPageDisclaimerPlease read.3DefinitionsList of definitions4Changes from 2010 CDR (December Update)List of changes from the 2010 CDR (December Update)6SummerSummaryShows load forecast, generation resources, and reserve margin for Summer 2011 through Summer 20207SummerCapacitiesLists units and their capabilities used in determining the generation resources in the Summer Summary9WinterSummaryShows load forecast, generation resources, and reserve margin for Winter 2011 through Winter 202025WinterCapacitiesLists units and their capabilities used in determining the generation resources in the Winter Summary27LongTermProjectionsGraphs of capacity and demand through 203143SummerFuelTypesLists generation fuel types by MW and by percentage for Summer 2011 through Summer 202045WinterFuelTypesLists generation fuel types by MW and by percentage for Winter 2011 through Winter 202046SummerLoadbyCountyShows estimated Summer non-coincident load by county for 2011 through 202047SummerGenerationbyCountyShows Summer generation by county for 2011 through 202054SummerImport-ExportbyCountyShows calculated import or export by county for Summer 2011 through Summer 202061WinterLoadbyCountyShows estimated Winter non-coincident load by county for 2011 through 202069WinterGenerationbyCountyShows Winter generation by county for 2011 through 202076WinterImport-ExportbyCountyShows calculated import or export by county for Winter 2011 through Winter 202083ContentsDisclaimerCDR WORKING PAPERFOR PLANNING PURPOSES ONLYThis ERCOT Working Paper has been prepared for specific ERCOT and market participant purposes and has been developed from dataprovidedby ERCOT market participants. The data may contain errors or become obsolete and thereby affect the conclusions and opinions of the WorkingPaper. ERCOT MAKES NO WARRANTY, EXPRESS OR IMPLIED, INCLUDING ANY WARRANTY OF MERCHANTABILITY OR FITNESS FORANY PARTICULAR PURPOSE, AND DISCLAIMS ANY AND ALL LIABILITY WITH RESPECT TO THE ACCURACY OF SAME OR THEFITNESS OR APPROPRIATENESS OF SAME FOR ANY PARTICULAR USE. THIS ERCOT WORKING PAPER IS SUPPLIED WITH ALLFAULTS. The specific suitability for any use of the Working Paper and its accuracy should be confirmed by each ERCOT market participant thatcontributed data for this Working Paper.This Working Paper is based on data submitted by ERCOT market participants as part of their Annual Load Data Request (ALDR) andtheirresource asset registration and on data in the EIA-411. As such, this data is updated on an ongoing basis, which means that this report can berendered obsolete without notice.Available Mothballed GenerationEffective Load-Carrying Capability (ELCC) of Wind GenerationForecast ZoneLaaRs (Loads acting as resources)Mothballed CapacityMothballed UnitNet Dependable CapabilityMaximum sustainable capability of a generation resource as demonstrated by performance testing.Non-Synchronous TieA generation resource for which a generation entity has submitted a Notification of Suspension of Operations, for which ERCOT has declined toexecute an RMR agreement, and for which the generation entity has not announced retirement of the generation resource.Any non-synchronous transmission interconnection between ERCOT and non-ERCOT electric power systemsThe difference in the available mothballed generation (see definition above) and the total mothballed capacity. This value iszero in the upcomingSummer CDR Report because there isn't enough time to return those units to service before the start of the summer.DefinitionsThe probability that a mothballed unit will return to service, as provided by its owner, multiplied by the capacity of the unit. Return probabilities areconsidered protected information under the ERCOT Protocols and therefore are not included in this report.The amount of wind generation that the Generation Adequacy Task Force (GATF) has recommended to be included in the CDR. The value is 8.7% ofthe nameplate capacity listed in the Unit Capacities tables, both installed capacity and planned capacity.Load capable of reducing or increasing the need for electrical energy or providing Ancillary Services to the ERCOT System, as described in the ERCOTProtocols, Section 6, Ancillary Services. These Resources may provide the following Ancillary Services: Responsive Reserve Service, Non-SpinningReserve Service, Replacement Reserve Service, and Regulation Service. The Resources must be registered and qualified by ERCOTand will bescheduled by a Qualified Scheduling EntityForecast Zones have the same boundaries as the 2003 ERCOT Congestion Management Zones. Each Resource will be mapped to a Forecast Zoneduring the registration process.Other Potential ResourcesCapacity resources that include one of the following:• Remaining "mothballed" capacity not included as resources in the reserve margin calculation• Remaining DC tie capacity not included as resources in the reserve margin calculation, andPlanned Units in Full Interconnection Study PhasePrivate NetworksReliability Must-Run (RMR) UnitSigned IA (Interconnection Agreement)Switchable UnitAn agreement that sets forth requirements for physical connection between an eligible transmission service customer and a transmission or distributionservice providerA generation resource that can be connected to either the ERCOT transmission grid or a grid outside the ERCOT Region.• New generating units that have initiated full transmission interconnection studies through the ERCOT generation interconnection process (Notethat new wind units would be included based on the appropriate discounted capacity value applied to existing wind generating units.)To connect new generation to the ERCOT grid, a generation developer must go through a set procedure. The first step is a high-level screening studyto determine the effects of adding the new generation on the transmission system. The second step is the full interconnection study. These aredetailed studies done by the transmission owners to determine the effects of the addition of new generation on the transmissionsystem.An electric network connected to the ERCOT transmission grid that contains load that is not directly metered by ERCOT (i.e., load that is typicallynetted with internal generation).A generation resource unit operated under the terms of an agreement with ERCOT that would not otherwise be operated except thatthey arenecessary to provide voltage support, stability or management of localized transmission constraints under first contingency criteria.1This report now incorporates a ten year planning horizon pursuant to recently approved Planning Guide 002.234Energy efficiency impacts based on 82R-SB1125 requirement for 0.4% of peak demand56INRSiteNameCapacityFuelFormer CODNew COD06INR0022c Penascal Wind Farm 3202 Wind Dec 2012 Dec 201310INR0022 Pondera King Power Project1,380 Gas Jun 2014 Jun 201512INR0016a Las Brisas Energy Center Phase 1620 Other Jul 2015Oct 201512INR0016b Las Brisas Energy Center Phase 2620 Other Jul 2016Oct 201614INR0002 Coleto Creek Unit 2660 Coal Jan 2016 Jan 2017Revision 1 2-Jun-11 Corrected double entry of a gas unit additionRevision 2 9-Jun-11 Corrected formulas that computed Winter potential resource totalsChanges from 2010 CDR (December Update)An increase in Operational Units capacity is due to the return to service of Greens Bayou 5, the addition of the Jack County Gas units, and the Lufkin Biomass unit.Units that are still in the interconnection study process are required to keep their planned in-service dates updated; Any updates provided by developers are reflected; ERCOT didnot explicitly survey all of these units, as they do not count toward the reserve margins.The 2011 forecast is included. The key inputs for this forecast are: 1) Moody's base economic forecast and 2) normalized weather. The 2011 forecasting process results in highpeak demands when compared to the 2010 forecast. The 2010 forecast utilized Moody's low economic forecast to better reflect prevailing economic conditions at that time.ERCOT surveyed all generators with Interconnection Agreements to update in-service dates; The committed projects shown on the table below have delayed their commercialoperations date:Load Forecast:2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Total Summer Peak Demand, MW63,898 65,665 67,757 70,54072,59174,198 75,365 76,654 77,866 79,274less LAARs Serving as Responsive Reserve, MW1,063 1,063 1,063 1,063 1,063 1,063 1,063 1,063 1,063 1,063less LAARs Serving as Non-Spinning Reserve, MW0000000000less Emergency Interruptible Load Service421 463 509 560 616 678 745 820 902 992less Energy Efficiency Programs (per SB1125)128 259 395 536 681 829 980 1133 1289 1448Firm Load Forecast, MW62,286 63,880 65,790 68,381 70,231 71,628 72,576 73,638 74,612 75,771Resources:2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Installed Capacity, MW63,859 63,859 63,859 63,859 63,859 63,859 63,859 63,859 63,859 63,859Capacity from Private Networks, MW5,023 5,071 5,074 5,074 5,074 5,074 5,074 5,074 5,074 5,074Effective Load-Carrying Capability (ELCC) of Wind Generation, MW 822 822 822 822 822 822 822 822 822 822RMR Units to be under Contract, MW0000000000Operational Generation, MW69,704 69,752 69,755 69,755 69,755 69,755 69,755 69,755 69,755 69,75550% of Non-Synchronous Ties, MW553 553 553 553 553 553 553 553 553 553Switchable Units, MW2,962 2,962 2,962 2,962 2,962 2,962 2,962 2,962 2,962 2,962Available Mothballed Generation , MW0 110 146 164 181 198 198 198 198 198Planned Units (not wind) with Signed IA and Air Permit, MW260 1,940 1,940 2,720 4,880 5,500 6,780 6,780 6,780 6,780ELCC of Planned Wind Units with Signed IA, MW13 65 113 131 131 131 131 131 131 131Total Resources, MW73,492 75,382 75,469 76,284 78,461 79,099 80,379 80,379 80,379 80,379less Switchable Units Unavailable to ERCOT, MW317 317 317 317 317 3170000less Retiring Units MW00000000002011 Report on the Capacity, Demand, and Reserves in the ERCOT RegionSummer SummarylessRetiringUnits,MW0000000000Resources, MW73,175 75,065 75,152 75,967 78,144 78,782 80,379 80,379 80,379 80,379Reserve Margin17.5% 17.5% 14.2% 11.1% 11.3% 10.0% 10.8% 9.2% 7.7% 6.1%(Resources - Firm Load Forecast)/Firm Load Forecast553 11,200 12,281 15,232 15,932 18,693 19,394 19,395 22,596 22,597Mothballed Capacity , MW0 2,447 2,411 2,393 2,376 2,359 2,359 2,359 2,359 2,35950% of Non-Synchronous Ties, MW553 553 553 553 553 553 554 555 556 557Planned Units in Full Interconnection Study Phase, MW0 8,200 9,317 12,285 13,003 15,781 16,481 16,481 19,681 19,681Other Potential Resources:2010 Report on the Capacity, Demand, and Reserves in the ERCOT RegionSummer Summary65,00070,00075,00080,00085,00090,000MWSummer Loads and Resources50,00055,00060,000,2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Firm Load ForecastResourcesForecast + Reserve MarginUnits used in determining the generation resources in the Summer SummaryUnit NameUnit CodeCounty FuelForecastZoneYear InService2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Coastal Plains RDF_AV_DG1Galveston Biomass Houston20036.7 6.7 6.7 6.7 6.7 6.7 6.7 6.7 6.7 6.7Atascocita 1_HB_DG1Harris Biomass Houston200310.1 10.1 10.1 10.1 10.1 10.1 10.1 10.1 10.1 10.1Bluebonnet 1_LB_DG1Harris Biomass Houston20033.9 3.9 3.9 3.9 3.9 3.9 3.9 3.9 3.9 3.9Amistad Hydro 1AMISTAD_AMISTAG1 Val Verde Hydro South198337.9 37.9 37.9 37.9 37.9 37.9 37.9 37.9 37.9 37.9Amistad Hydro 2AMISTAD_AMISTAG2 Val Verde Hydro South198337.9 37.9 37.9 37.9 37.9 37.9 37.9 37.9 37.9 37.9AES DeepwaterAPD_APD_PS1Harris Other Houston20101.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0Atkins 7ATKINS_ATKINSG7 Brazos Gas North197320.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0Austin 1AUSTPL_AUSTING1 Travis Hydro South19408.0 8.0 8.0 8.0 8.0 8.0 8.0 8.0 8.0 8.0Austin 2AUSTPL_AUSTING2 Travis Hydro South19409.0 9.0 9.0 9.0 9.0 9.0 9.0 9.0 9.0 9.0ExTex La Porte Pwr Stn (AirPro) 1 AZ_AZ_G1Harris Gas Houston200938.0 38.0 38.0 38.0 38.0 38.0 38.0 38.0 38.0 38.0ExTex La Porte Pwr Stn (AirPro) 2 AZ_AZ_G2Harris Gas Houston200938.0 38.0 38.0 38.0 38.0 38.0 38.0 38.0 38.0 38.0ExTex La Porte Pwr Stn(AirPro) 3 AZ_AZ_G3Harris Gas Houston200938.0 38.0 38.0 38.0 38.0 38.0 38.0 38.0 38.0 38.0ExTex La Porte Pwr Stn (AirPro) 4 AZ_AZ_G4Harris Gas Houston200938.0 38.0 38.0 38.0 38.0 38.0 38.0 38.0 38.0 38.0B M Davis 1B_DAVIS_B_DAVIG1 Nueces Gas South1974335.0 335.0 335.0 335.0 335.0 335.0 335.0 335.0 335.0 335.0B M Davis 2B_DAVIS_B_DAVIG2 Nueces Gas South1976308.0 308.0 308.0 308.0 308.0 308.0 308.0 308.0 308.0 308.0B M Davis 3B_DAVIS_B_DAVIG3 Nueces Gas South2009175.1 175.1 175.1 175.1 175.1 175.1 175.1 175.1 175.1 175.1B M Davis 4B_DAVIS_B_DAVIG4 Nueces Gas South2009175.1 175.1 175.1 175.1 175.1 175.1 175.1 175.1 175.1 175.1Bastrop Energy Center 1BASTEN_GTG1100 Bastrop Gas South2002150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0Bastrop Energy Center 2BASTEN_GTG2100 Bastrop Gas South2002150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0Bastrop Energy Center 3BASTEN_ST0100Bastrop Gas South2002233.0 233.0 233.0 233.0 233.0 233.0 233.0 233.0 233.0 233.0Big Brown 1BBSES_UNIT1Freestone Coal North1971600.0 600.0 600.0 600.0 600.0 600.0 600.0 600.0 600.0 600.0Big Brown 2BBSES_UNIT2Freestone Coal North1972595.0 595.0 595.0 595.0 595.0 595.0 595.0 595.0 595.0 595.0Bosque County Peaking 1BOSQUESW_BSQSU_1 Bosque Gas North2000153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0Bosque County Peaking 2BOSQUESW_BSQSU_2 Bosque Gas North2000153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0Bosque County Peaking 3BOSQUESW BSQSU 3BosqueGasNorth2001154.0154.0154.0154.0154.0154.0154.0154.0154.0154.0Unit Capacities - SummerOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. Thislist includes MW available to the grid from private network (self-serve) units. It also includes distributed generationunits that have registered with ERCOT. Data without unit names are for private network units or are planned generation that isnot public.BosqueCountyPeaking3BOSQUESW_BSQSU_3BosqueGasNorth2001154.0154.0154.0154.0154.0154.0154.0154.0154.0154.0Bosque County Peaking 4BOSQUESW_BSQSU_4 Bosque Gas North200183.0 83.0 83.0 83.0 83.0 83.0 83.0 83.0 83.0 83.0Bosque County Unit 5BOSQUESW_BSQSU_5 Bosque Gas North2009240.0 240.0 240.0 240.0 240.0 240.0 240.0 240.0 240.0 240.0A von Rosenberg 1-CT1BRAUNIG_AVR1_CT1 Bexar Gas South2000145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0A von Rosenberg 1-CT2BRAUNIG_AVR1_CT2 Bexar Gas South2000145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0A von Rosenberg 1-ST1BRAUNIG_AVR1_ST Bexar Gas South2000160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0V H Braunig 1BRAUNIG_VHB1Bexar Gas South1966215.0 215.0 215.0 215.0 215.0 215.0 215.0 215.0 215.0 215.0V H Braunig 2BRAUNIG_VHB2Bexar Gas South1968220.0 220.0 220.0 220.0 220.0 220.0 220.0 220.0 220.0 220.0V H Braunig 3BRAUNIG_VHB3Bexar Gas South1970412.0 412.0 412.0 412.0 412.0 412.0 412.0 412.0 412.0 412.0V H Braunig 5BRAUNIG_VHB6CT5 Bexar Gas South200948.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0V H Braunig 6BRAUNIG_VHB6CT6 Bexar Gas South200948.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0V H Braunig 7BRAUNIG_VHB6CT7 Bexar Gas South200948.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0V H Braunig 8BRAUNIG_VHB6CT8 Bexar Gas South200948.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Buchanan 1BUCHAN_BUCHANG1 Llano Hydro South193818.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0Buchanan 2BUCHAN_BUCHANG2 Llano Hydro South193818.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0Buchanan 3BUCHAN_BUCHANG3 Llano Hydro South195018.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0Brazos Valley 1BVE_UNIT1Ft Bend Gas Houston2003163.0 163.0 163.0 163.0 163.0 163.0 163.0 163.0 163.0 163.0Brazos Valley 2BVE_UNIT2Ft Bend Gas Houston2003163.0 163.0 163.0 163.0 163.0 163.0 163.0 163.0 163.0 163.0Brazos Valley 3BVE_UNIT3Ft Bend Gas Houston2003253.0 253.0 253.0 253.0 253.0 253.0 253.0 253.0 253.0 253.0J K Spruce 1CALAVERS_JKS1Bexar Coal South1992555.0 555.0 555.0 555.0 555.0 555.0 555.0 555.0 555.0 555.0J K Spruce 2CALAVERS_JKS2Bexar Coal South2010785.0 785.0 785.0 785.0 785.0 785.0 785.0 785.0 785.0 785.0J T Deely 1CALAVERS_JTD1Bexar Coal South1977440.0 440.0 440.0 440.0 440.0 440.0 440.0 440.0 440.0 440.0J T Deely 2CALAVERS_JTD2Bexar Coal South1978440.0 440.0 440.0 440.0 440.0 440.0 440.0 440.0 440.0 440.0O W Sommers 1CALAVERS_OWS1Bexar Gas South1972420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0Units used in determining the generation resources in the Summer SummaryUnit NameUnit CodeCounty FuelForecastZoneYear InService2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Unit Capacities - SummerOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. Thislist includes MW available to the grid from private network (self-serve) units. It also includes distributed generationunits that have registered with ERCOT. Data without unit names are for private network units or are planned generation that isnot public.O W Sommers 2CALAVERS_OWS2Bexar Gas South1974420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0Canyon 1CANYHY_CANYHYG1 Comal Hydro South19893.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0Canyon 2CANYHY_CANYHYG2 Comal Hydro South19893.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0Colorado Bend Energy Center CBEC_GT1Wharton Gas Houston200775.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0Colorado Bend Energy Center CBEC_GT2Wharton Gas Houston200769.0 69.0 69.0 69.0 69.0 69.0 69.0 69.0 69.0 69.0Colorado Bend Energy Center CBEC_GT3Wharton Gas Houston200877.0 77.0 77.0 77.0 77.0 77.0 77.0 77.0 77.0 77.0Colorado Bend Energy Center CBEC_GT4Wharton Gas Houston200871.0 71.0 71.0 71.0 71.0 71.0 71.0 71.0 71.0 71.0Colorado Bend Energy Center CBEC_STG1Wharton Gas Houston2007103.0 103.0 103.0 103.0 103.0 103.0 103.0 103.0 103.0 103.0Colorado Bend Energy Center CBEC_STG2Wharton Gas Houston2008104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0Cedar Bayou 1CBY_CBY_G1Chambers Gas Houston1970745.0 745.0 745.0 745.0 745.0 745.0 745.0 745.0 745.0 745.0Cedar Bayou 2CBY_CBY_G2Chambers Gas Houston1972749.0 749.0 749.0 749.0 749.0 749.0 749.0 749.0 749.0 749.0Cedar Bayou 4CBY4_CT41Chambers Gas Houston2009180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0Cedar Bayou 5CBY4_CT42Chambers Gas Houston2009180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0Cedar Bayou 6CBY4_ST04Chambers Gas Houston2009190.0 190.0 190.0 190.0 190.0 190.0 190.0 190.0 190.0 190.0Coleto CreekCOLETO_COLETOG1 Goliad Coal South1980640.0 640.0 640.0 640.0 640.0 640.0 640.0 640.0 640.0 640.0Comanche Peak 1CPSES_UNIT1Somervell Nuclear North19901210.0 1210.0 1210.0 1210.0 1210.0 1210.0 1210.0 1210.0 1210.0 1210.0Comanche Peak 2CPSES_UNIT2Somervell Nuclear North19931197.0 1197.0 1197.0 1197.0 1197.0 1197.0 1197.0 1197.0 1197.0 1197.0Small Hydro of Texas 1CUECPL_UNIT1Dewitt Hydro South19921.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0CVC Channelview 1CVC_CVC_G1Harris Gas Houston2008156.0 156.0 156.0 156.0 156.0 156.0 156.0 156.0 156.0 156.0CVC Channelview 2CVC_CVC_G2Harris Gas Houston2008158.0 158.0 158.0 158.0 158.0 158.0 158.0 158.0 158.0 158.0CVC Channelview 3CVC_CVC_G3Harris Gas Houston2008160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0CVC Channelview 5CVC_CVC_G5Harris Gas Houston2008122.0 122.0 122.0 122.0 122.0 122.0 122.0 122.0 122.0 122.0Dansby 1DANSBY_DANSBYG1 Brazos Gas North1978110.0 110.0 110.0 110.0 110.0 110.0 110.0 110.0 110.0 110.0Dansby 2DANSBY_DANSBYG2 Brazos Gas North200448.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Dansby 3DANSBY DANSBYG3BrazosGasNorth201048.048.048.048.048.048.048.048.048.048.0Dansby3DANSBY_DANSBYG3DeCordova ADCSES_CT10Hood Gas North201071.0 71.0 71.0 71.0 71.0 71.0 71.0 71.0 71.0 71.0DeCordova BDCSES_CT20Hood Gas North201070.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0DeCordova CDCSES_CT30Hood Gas North201069.0 69.0 69.0 69.0 69.0 69.0 69.0 69.0 69.0 69.0DeCordova DDCSES_CT40Hood Gas North201068.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0Deer Park Energy Center 1DDPEC_GT1Harris Gas Houston2002163.2 163.2 163.2 163.2 163.2 163.2 163.2 163.2 163.2 163.2Deer Park Energy Center 2DDPEC_GT2Harris Gas Houston2002157.1 157.1 157.1 157.1 157.1 157.1 157.1 157.1 157.1 157.1Deer Park Energy Center 3DDPEC_GT3Harris Gas Houston2002157.5 157.5 157.5 157.5 157.5 157.5 157.5 157.5 157.5 157.5Deer Park Energy Center 4DDPEC_GT4Harris Gas Houston2002157.0 157.0 157.0 157.0 157.0 157.0 157.0 157.0 157.0 157.0Deer Park Energy Center SDDPEC_ST1Harris Gas Houston2002238.2 238.2 238.2 238.2 238.2 238.2 238.2 238.2 238.2 238.2Decker Creek 1DECKER_DPG1Travis Gas South2000315.0 315.0 315.0 315.0 315.0 315.0 315.0 315.0 315.0 315.0Decker Creek 2DECKER_DPG2Travis Gas South2000420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0Decker Creek G1DECKER_DPGT_1Travis Gas South200048.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Decker Creek G2DECKER_DPGT_2Travis Gas South200048.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Decker Creek G3DECKER_DPGT_3Travis Gas South200048.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Decker Creek G4DECKER_DPGT_4Travis Gas South200048.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Rhodia Houston PlantDG__HG_2UNITSHarris Other Houston19707.5 7.5 7.5 7.5 7.5 7.5 7.5 7.5 7.5 7.5Oak Ridge North 1-3DG__RA_3UNITSMontgomery Other Houston19934.8 4.8 4.8 4.8 4.8 4.8 4.8 4.8 4.8 4.8Fresno EnergyDG__SO_1UNITFort Bend Other Houston20101.6 1.6 1.6 1.6 1.6 1.6 1.6 1.6 1.6 1.6DFW Gas RecoveryDG_BIO2_4UNITSDenton Biomass North19806.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4Bio Energy PartnersDG_BIOE_2UNITSDenton Gas North19885.6 5.6 5.6 5.6 5.6 5.6 5.6 5.6 5.6 5.6Skyline Landfill GasDG_FERIS_4UNITS Dallas Other North20076.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4Trinity Oaks LFGDG_KLBRG_1UNITDallas Biomass North20093.2 3.2 3.2 3.2 3.2 3.2 3.2 3.2 3.2 3.2GBRA 4 & 5DG_LKWDT_2UNITS Gonzales Other South19314.8 4.8 4.8 4.8 4.8 4.8 4.8 4.8 4.8 4.8Units used in determining the generation resources in the Summer SummaryUnit NameUnit CodeCounty FuelForecastZoneYear InService2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Unit Capacities - SummerOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. Thislist includes MW available to the grid from private network (self-serve) units. It also includes distributed generationunits that have registered with ERCOT. Data without unit names are for private network units or are planned generation that isnot public.Lewisville 1 DG_LWSVL_1UNIT Denton Hydro North19922.8 2.8 2.8 2.8 2.8 2.8 2.8 2.8 2.8 2.8McQueeney (Abbott) DG_MCQUE_5UNITS Guadalupe Hydro South19278.0 8.0 8.0 8.0 8.0 8.0 8.0 8.0 8.0 8.0Covel Gardens LG Power StnDG_MEDIN_1UNITBexar Other South200510.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0Nelson Gardens Landfill 1DG_PEARS_2UNITS Bexar Other South19903.6 3.6 3.6 3.6 3.6 3.6 3.6 3.6 3.6 3.6FW Region LFG Gen Facility 1 DG_RDLML_1UNITTarrant Other North19881.5 1.5 1.5 1.5 1.5 1.5 1.5 1.5 1.5 1.5RGV Sugar MillDG_S_SNR_UNIT1Hidalgo Biomass South19734.5 4.5 4.5 4.5 4.5 4.5 4.5 4.5 4.5 4.5Dunlop (Schumansville) 1DG_SCHUM_2UNITS Guadalupe Hydro South19273.6 3.6 3.6 3.6 3.6 3.6 3.6 3.6 3.6 3.6Austin Landfill GasDG_SPRIN_4UNITS Travis Other South19886.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4AEDOMG 1DG_SUMMI_1UNITTravis Gas South20045.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0Tessman Road 1DG_WALZE_4UNITS Bexar Biomass South200310.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0Denison Dam 1DNDAM_DENISOG1 Grayson Hydro North194440.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0Denison Dam 2DNDAM_DENISOG2 Grayson Hydro North194840.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0Hidalgo 1DUKE_DUKE_GT1Hidalgo Gas South2000145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0Hidalgo 2DUKE_DUKE_GT2Hidalgo Gas South2000145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0Hidalgo 3DUKE_DUKE_ST1Hidalgo Gas South2000170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0Eagle Pass 1EAGLE_HY_EAGLE_HY1 Maverick Hydro South19542.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0Eagle Pass 2EAGLE_HY_EAGLE_HY2 Maverick Hydro South19542.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0Eagle Pass 3EAGLE_HY_EAGLE_HY3 Maverick Hydro South19542.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0Ennis Power Station 2ETCCS_CT1Ellis Gas North2002196.0 196.0 196.0 196.0 196.0 196.0 196.0 196.0 196.0 196.0Ennis Power Station 1ETCCS_UNIT1Ellis Gas North2002116.0 116.0 116.0 116.0 116.0 116.0 116.0 116.0 116.0 116.0Falcon Hydro 1FALCON_FALCONG1 Starr Hydro South195412.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0Falcon Hydro 2FALCON_FALCONG2 Starr Hydro South195412.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0Falcon Hydro 3FALCON_FALCONG3 Starr Hydro South195412.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0Thomas C Ferguson 1FERGUS_FERGUSG1 Llano Gas South1974424.0 424.0 424.0 424.0 424.0 424.0 424.0 424.0 424.0 424.0Calenergy (Falcon Seaboard) 1FLCNS UNIT1HowardGasWest198775.075.075.075.075.075.075.075.075.075.0Calenergy(FalconSeaboard)1FLCNS_UNIT1Calenergy (Falcon Seaboard) 2 FLCNS_UNIT2Howard Gas West198775.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0Calenergy (Falcon Seaboard) 3 FLCNS_UNIT3Howard Gas West198870.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0Fayette Power Project 1FPPYD1_FPP_G1Fayette Coal South1979608.0 608.0 608.0 608.0 608.0 608.0 608.0 608.0 608.0 608.0Fayette Power Project 2FPPYD1_FPP_G2Fayette Coal South1980608.0 608.0 608.0 608.0 608.0 608.0 608.0 608.0 608.0 608.0Fayette Power Project 3FPPYD2_FPP_G3Fayette Coal South1988445.0 445.0 445.0 445.0 445.0 445.0 445.0 445.0 445.0 445.0Freestone Energy Center 1FREC_GT1Freestone Gas North2002152.0 152.0 152.0 152.0 152.0 152.0 152.0 152.0 152.0 152.0Freestone Energy Center 2FREC_GT2Freestone Gas North2002152.0 152.0 152.0 152.0 152.0 152.0 152.0 152.0 152.0 152.0Freestone Energy Center 4FREC_GT4Freestone Gas North2002152.0 152.0 152.0 152.0 152.0 152.0 152.0 152.0 152.0 152.0Freestone Energy Center 5FREC_GT5Freestone Gas North2002152.0 152.0 152.0 152.0 152.0 152.0 152.0 152.0 152.0 152.0Freestone Energy Center 3FREC_ST3Freestone Gas North2002175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0Freestone Energy Center 6FREC_ST6Freestone Gas North2002175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0Forney Energy Center GT11FRNYPP_GT11Kaufman Gas North2003178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2Forney Energy Center GT12FRNYPP_GT12Kaufman Gas North2003178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2Forney Energy Center GT13FRNYPP_GT13Kaufman Gas North2003178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2Forney Energy Center GT21FRNYPP_GT21Kaufman Gas North2003178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2Forney Energy Center GT22FRNYPP_GT22Kaufman Gas North2003178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2Forney Energy Center GT23FRNYPP_GT23Kaufman Gas North2003178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2 178.2Forney Energy Center STG10FRNYPP_ST10Kaufman Gas North2003405.0 405.0 405.0 405.0 405.0 405.0 405.0 405.0 405.0 405.0Forney Energy Center STG20FRNYPP_ST20Kaufman Gas North2003405.0 405.0 405.0 405.0 405.0 405.0 405.0 405.0 405.0 405.0Frontera 1FRONTERA_FRONTEG1 Hidalgo Gas South1999141.0 141.0 141.0 141.0 141.0 141.0 141.0 141.0 141.0 141.0Frontera 2FRONTERA_FRONTEG2 Hidalgo Gas South1999141.0 141.0 141.0 141.0 141.0 141.0 141.0 141.0 141.0 141.0Frontera 3FRONTERA_FRONTEG3 Hidalgo Gas South2000173.0 173.0 173.0 173.0 173.0 173.0 173.0 173.0 173.0 173.0Greens Bayou 5GBY_GBY_5Harris Gas Houston1973406.0 406.0 406.0 406.0 406.0 406.0 406.0 406.0 406.0 406.0Units used in determining the generation resources in the Summer SummaryUnit NameUnit CodeCounty FuelForecastZoneYear InService2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Unit Capacities - SummerOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. Thislist includes MW available to the grid from private network (self-serve) units. It also includes distributed generationunits that have registered with ERCOT. Data without unit names are for private network units or are planned generation that isnot public.Greens Bayou 73GBY_GBYGT73Harris Gas Houston197646.0 46.0 46.0 46.0 46.0 46.0 46.0 46.0 46.0 46.0Greens Bayou 74GBY_GBYGT74Harris Gas Houston197646.0 46.0 46.0 46.0 46.0 46.0 46.0 46.0 46.0 46.0Greens Bayou 81GBY_GBYGT81Harris Gas Houston197646.0 46.0 46.0 46.0 46.0 46.0 46.0 46.0 46.0 46.0Greens Bayou 82GBY_GBYGT82Harris Gas Houston197658.0 58.0 58.0 58.0 58.0 58.0 58.0 58.0 58.0 58.0Greens Bayou 83GBY_GBYGT83Harris Gas Houston197656.0 56.0 56.0 56.0 56.0 56.0 56.0 56.0 56.0 56.0Greens Bayou 84GBY_GBYGT84Harris Gas Houston197658.0 58.0 58.0 58.0 58.0 58.0 58.0 58.0 58.0 58.0Gibbons Creek 1GIBCRK_GIB_CRG1 Grimes Coal North1982470.0 470.0 470.0 470.0 470.0 470.0 470.0 470.0 470.0 470.0Sim Gideon 1GIDEON_GIDEONG1 Bastrop Gas South1965136.0 136.0 136.0 136.0 136.0 136.0 136.0 136.0 136.0 136.0Sim Gideon 2GIDEON_GIDEONG2 Bastrop Gas South1968136.0 136.0 136.0 136.0 136.0 136.0 136.0 136.0 136.0 136.0Sim Gideon 3GIDEON_GIDEONG3 Bastrop Gas South1972336.0 336.0 336.0 336.0 336.0 336.0 336.0 336.0 336.0 336.0Graham 1GRSES_UNIT1Young Gas West1960225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0Graham 2GRSES_UNIT2Young Gas West1969390.0 390.0 390.0 390.0 390.0 390.0 390.0 390.0 390.0 390.0Guadalupe Gen Stn 1GUADG_GAS1Guadalupe Gas South2000151.0 151.0 151.0 151.0 151.0 151.0 151.0 151.0 151.0 151.0Guadalupe Gen Stn 2GUADG_GAS2Guadalupe Gas South2000151.0 151.0 151.0 151.0 151.0 151.0 151.0 151.0 151.0 151.0Guadalupe Gen Stn 3GUADG_GAS3Guadalupe Gas South2000149.0 149.0 149.0 149.0 149.0 149.0 149.0 149.0 149.0 149.0Guadalupe Gen Stn 4GUADG_GAS4Guadalupe Gas South2000152.0 152.0 152.0 152.0 152.0 152.0 152.0 152.0 152.0 152.0Guadalupe Gen Stn 5GUADG_STM5Guadalupe Gas South2000170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0Guadalupe Gen Stn 6GUADG_STM6Guadalupe Gas South2000169.0 169.0 169.0 169.0 169.0 169.0 169.0 169.0 169.0 169.0Hays Energy Facility 1HAYSEN_HAYSENG1 Hays Gas South2002216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0Hays Energy Facility 2HAYSEN_HAYSENG2 Hays Gas South2002216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0Hays Energy Facility 3HAYSEN_HAYSENG3 Hays Gas South2002225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0Hays Energy Facility 4HAYSEN_HAYSENG4 Hays Gas South2002225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0Handley 3HLSES_UNIT3Tarrant Gas North1963395.0 395.0 395.0 395.0 395.0 395.0 395.0 395.0 395.0 395.0Handley 4HLSES_UNIT4Tarrant Gas North1976435.0 435.0 435.0 435.0 435.0 435.0 435.0 435.0 435.0 435.0Handley 5HLSES UNIT5TarrantGasNorth1977435.0435.0435.0435.0435.0435.0435.0435.0435.0435.0Handley5HLSES_UNIT5TarrantInks 1INKSDA_INKS_G1Llano Hydro South193814.0 14.0 14.0 14.0 14.0 14.0 14.0 14.0 14.0 14.0Jack County GenFacility 1JACKCNTY_CT1Jack Gas North2005142.0 142.0 142.0 142.0 142.0 142.0 142.0 142.0 142.0 142.0Jack County GenFacility 1JACKCNTY_CT2Jack Gas North2005142.0 142.0 142.0 142.0 142.0 142.0 142.0 142.0 142.0 142.0Jack County GenFacility 1JACKCNTY_STGJack Gas North2005281.0 281.0 281.0 281.0 281.0 281.0 281.0 281.0 281.0 281.0Laredo Peaking 4LARDVFTN_G4Webb Gas South200894.2 94.2 94.2 94.2 94.2 94.2 94.2 94.2 94.2 94.2Laredo Peaking 5LARDVFTN_G5Webb Gas South200894.2 94.2 94.2 94.2 94.2 94.2 94.2 94.2 94.2 94.2Limestone 1LEG_LEG_G1Limestone Coal North1985831.0 831.0 831.0 831.0 831.0 831.0 831.0 831.0 831.0 831.0Limestone 2LEG_LEG_G2Limestone Coal North1986858.0 858.0 858.0 858.0 858.0 858.0 858.0 858.0 858.0 858.0Leon Creek Peaking 1LEON_CRK_LCPCT1 Bexar Gas South200445.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0Leon Creek Peaking 2LEON_CRK_LCPCT2 Bexar Gas South200445.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0Leon Creek Peaking 3LEON_CRK_LCPCT3 Bexar Gas South200445.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0Leon Creek Peaking 4LEON_CRK_LCPCT4 Bexar Gas South200445.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0Lufkin BiomassLFBIO_UNIT1Angelina Biomass North201145.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0Lake Hubbard 2LH2SES_UNIT2Dallas Gas North2010524.0 524.0 524.0 524.0 524.0 524.0 524.0 524.0 524.0 524.0Lake Hubbard 1LHSES_UNIT1Dallas Gas North1970392.0 392.0 392.0 392.0 392.0 392.0 392.0 392.0 392.0 392.0Lost Pines 1LOSTPI_LOSTPGT1 Bastrop Gas South2001167.0 167.0 167.0 167.0 167.0 167.0 167.0 167.0 167.0 167.0Lost Pines 2LOSTPI_LOSTPGT2 Bastrop Gas South2001164.0 164.0 164.0 164.0 164.0 164.0 164.0 164.0 164.0 164.0Lost Pines 3LOSTPI_LOSTPST1 Bastrop Gas South2001184.0 184.0 184.0 184.0 184.0 184.0 184.0 184.0 184.0 184.0Lamar Power Project CT11LPCCS_CT11Lamar Gas North2000166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0Lamar Power Project CT12LPCCS_CT12Lamar Gas North2000166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0Lamar Power Project CT21LPCCS_CT21Lamar Gas North2000166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0Lamar Power Project CT22LPCCS_CT22Lamar Gas North2000166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0Lamar Power Project STG1LPCCS_UNIT1Lamar Gas North2000204.3 204.3 204.3 204.3 204.3 204.3 204.3 204.3 204.3 204.3Units used in determining the generation resources in the Summer SummaryUnit NameUnit CodeCounty FuelForecastZoneYear InService2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Unit Capacities - SummerOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. Thislist includes MW available to the grid from private network (self-serve) units. It also includes distributed generationunits that have registered with ERCOT. Data without unit names are for private network units or are planned generation that isnot public.Lamar Power Project STG2LPCCS_UNIT2Lamar Gas North2000204.3 204.3 204.3 204.3 204.3 204.3 204.3 204.3 204.3 204.3Marble Falls 1MARBFA_MARBFAG1 Burnet Hydro South195121.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0Marble Falls 2MARBFA_MARBFAG2 Burnet Hydro South195121.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0Marshall Ford 1MARSFO_MARSFOG1 Travis Hydro South194136.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0Marshall Ford 2MARSFO_MARSFOG2 Travis Hydro South194136.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0Marshall Ford 3MARSFO_MARSFOG3 Travis Hydro South194129.0 29.0 29.0 29.0 29.0 29.0 29.0 29.0 29.0 29.0Mountain Creek 6MCSES_UNIT6Dallas Gas North1956120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0Mountain Creek 7MCSES_UNIT7Dallas Gas North1958115.0 115.0 115.0 115.0 115.0 115.0 115.0 115.0 115.0 115.0Mountain Creek 8MCSES_UNIT8Dallas Gas North1967565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0Midlothian 1MDANP_CT1Ellis Gas North2001216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0Midlothian 2MDANP_CT2Ellis Gas North2001216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0Midlothian 3MDANP_CT3Ellis Gas North2001216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0Midlothian 4MDANP_CT4Ellis Gas North2001216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0Midlothian 5MDANP_CT5Ellis Gas North2002225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0Midlothian 6MDANP_CT6Ellis Gas North2002225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0Morgan Creek AMGSES_CT1Mitchell Gas West198868.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0Morgan Creek BMGSES_CT2Mitchell Gas West198868.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0Morgan Creek CMGSES_CT3Mitchell Gas West198868.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0Morgan Creek DMGSES_CT4Mitchell Gas West198868.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0Morgan Creek EMGSES_CT5Mitchell Gas West198868.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0Morgan Creek FMGSES_CT6Mitchell Gas West198867.0 67.0 67.0 67.0 67.0 67.0 67.0 67.0 67.0 67.0R W Miller 1MIL_MILLERG1Palo Pinto Gas North200075.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0R W Miller 2MIL_MILLERG2Palo Pinto Gas North2000120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0R W Miller 3MIL_MILLERG3Palo Pinto Gas North2000208.0 208.0 208.0 208.0 208.0 208.0 208.0 208.0 208.0 208.0R W Miller 4MIL MILLERG4Palo PintoGasNorth2000104.0104.0104.0104.0104.0104.0104.0104.0104.0104.0RWMiller4MIL_MILLERG4PaloPintoR W Miller 5MIL_MILLERG5Palo Pinto Gas North2000104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0Martin Lake 1MLSES_UNIT1Rusk Coal North1977805.0 805.0 805.0 805.0 805.0 805.0 805.0 805.0 805.0 805.0Martin Lake 2MLSES_UNIT2Rusk Coal North1978810.0 810.0 810.0 810.0 810.0 810.0 810.0 810.0 810.0 810.0Martin Lake 3MLSES_UNIT3Rusk Coal North1979810.0 810.0 810.0 810.0 810.0 810.0 810.0 810.0 810.0 810.0Monticello 1MNSES_UNIT1Titus Coal North1974565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0Monticello 2MNSES_UNIT2Titus Coal North1975565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0Monticello 3MNSES_UNIT3Titus Coal North1978760.0 760.0 760.0 760.0 760.0 760.0 760.0 760.0 760.0 760.0Magic Valley 1NEDIN_NEDIN_G1Hidalgo Gas South2001190.0 190.0 190.0 190.0 190.0 190.0 190.0 190.0 190.0 190.0Magic Valley 2NEDIN_NEDIN_G2Hidalgo Gas South2001190.0 190.0 190.0 190.0 190.0 190.0 190.0 190.0 190.0 190.0Magic Valley 3NEDIN_NEDIN_G3Hidalgo Gas South2001210.0 210.0 210.0 210.0 210.0 210.0 210.0 210.0 210.0 210.0Nueces Bay 7NUECES_B_NUECESG7 Nueces Gas South1972308.0 308.0 308.0 308.0 308.0 308.0 308.0 308.0 308.0 308.0Nueces Bay 8NUECES_B_NUECESG8 Nueces Gas South2009175.1 175.1 175.1 175.1 175.1 175.1 175.1 175.1 175.1 175.1Nueces Bay 9NUECES_B_NUECESG9 Nueces Gas South2009175.1 175.1 175.1 175.1 175.1 175.1 175.1 175.1 175.1 175.1Odessa-Ector Gen Stn C11OECCS_CT11Ector Gas West2001146.0 146.0 146.0 146.0 146.0 146.0 146.0 146.0 146.0 146.0Odessa-Ector Gen Stn C12OECCS_CT12Ector Gas West2001139.0 139.0 139.0 139.0 139.0 139.0 139.0 139.0 139.0 139.0Odessa-Ector Gen Stn C21OECCS_CT21Ector Gas West2001135.0 135.0 135.0 135.0 135.0 135.0 135.0 135.0 135.0 135.0Odessa-Ector Gen Stn C22OECCS_CT22Ector Gas West2001153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0Odessa-Ector Gen Stn ST1OECCS_UNIT1Ector Gas West2001210.0 210.0 210.0 210.0 210.0 210.0 210.0 210.0 210.0 210.0Odessa-Ector Gen Stn ST2OECCS_UNIT2Ector Gas West2001210.0 210.0 210.0 210.0 210.0 210.0 210.0 210.0 210.0 210.0Oak Grove SES Unit 1OGSES_UNIT1ARobertson Coal North2011820.0 820.0 820.0 820.0 820.0 820.0 820.0 820.0 820.0 820.0Oak Grove SES Unit 2OGSES_UNIT2Robertson Coal North2011796.0 796.0 796.0 796.0 796.0 796.0 796.0 796.0 796.0 796.0Oklaunion 1OKLA_OKLA_G1Wilbarger Coal West1986650.0 650.0 650.0 650.0 650.0 650.0 650.0 650.0 650.0 650.0Ray Olinger 1OLINGR_OLING_1Collin Gas North196778.0 78.0 78.0 78.0 78.0 78.0 78.0 78.0 78.0 78.0Units used in determining the generation resources in the Summer SummaryUnit NameUnit CodeCounty FuelForecastZoneYear InService2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Unit Capacities - SummerOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. Thislist includes MW available to the grid from private network (self-serve) units. It also includes distributed generationunits that have registered with ERCOT. Data without unit names are for private network units or are planned generation that isnot public.Ray Olinger 2OLINGR_OLING_2Collin Gas North1971107.0 107.0 107.0 107.0 107.0 107.0 107.0 107.0 107.0 107.0Ray Olinger 3OLINGR_OLING_3Collin Gas North1975146.0 146.0 146.0 146.0 146.0 146.0 146.0 146.0 146.0 146.0Ray Olinger 4OLINGR_OLING_4Collin Gas North200175.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0Permian Basin APB2SES_CT1Ward Gas West198868.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0Permian Basin BPB2SES_CT2Ward Gas West198865.0 65.0 65.0 65.0 65.0 65.0 65.0 65.0 65.0 65.0Permian Basin CPB2SES_CT3Ward Gas West198868.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0 68.0Permian Basin DPB2SES_CT4Ward Gas West199069.0 69.0 69.0 69.0 69.0 69.0 69.0 69.0 69.0 69.0Permian Basin EPB2SES_CT5Ward Gas West199070.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0Pearsall Engine PlantPEARSAL2_ENG1FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG10 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG11 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG12 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG13 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG14 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG15 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG16 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG17 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG18 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG19 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG2FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG20 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG21 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG22 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG23 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2 ENG24FrioGasSouth20108.48.48.48.48.48.48.48.48.48.4PearsallEnginePlantPEARSAL2_ENG24Pearsall Engine PlantPEARSAL2_ENG3FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG4FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG5FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG6FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG7FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG8FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG9FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall 1PEARSALL_PEARS_1 FrioGas South196125.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0Pearsall 2PEARSALL_PEARS_2 FrioGas South196125.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0Pearsall 3PEARSALL_PEARS_3 FrioGas South196125.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0PasGenPSG_PSG_GT2Harris Gas Houston2000161.0 161.0 161.0 161.0 161.0 161.0 161.0 161.0 161.0 161.0PasGenPSG_PSG_GT3Harris Gas Houston2000161.0 161.0 161.0 161.0 161.0 161.0 161.0 161.0 161.0 161.0PasGenPSG_PSG_ST2Harris Gas Houston2000177.0 177.0 177.0 177.0 177.0 177.0 177.0 177.0 177.0 177.0Quail Run Energy STG1QALSW_GT1Ector Gas West200774.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0Quail Run Energy GT1QALSW_GT2Ector Gas West200774.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0Quail Run Energy GT2QALSW_GT3Ector Gas West200872.0 72.0 72.0 72.0 72.0 72.0 72.0 72.0 72.0 72.0Quail Run Energy STG2QALSW_GT4Ector Gas West200872.0 72.0 72.0 72.0 72.0 72.0 72.0 72.0 72.0 72.0Quail Run Energy GT3QALSW_STG1Ector Gas West2007102.0 102.0 102.0 102.0 102.0 102.0 102.0 102.0 102.0 102.0Quail Run Energy GT4QALSW_STG2Ector Gas West200898.0 98.0 98.0 98.0 98.0 98.0 98.0 98.0 98.0 98.0Rayburn 1RAYBURN_RAYBURG1 Victoria Gas South196311.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0Rayburn 10RAYBURN_RAYBURG10 Victoria Gas South200340.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0Rayburn 2RAYBURN_RAYBURG2 Victoria Gas South196311.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0 11.0Rayburn 3RAYBURN_RAYBURG3 Victoria Gas South196524.0 24.0 24.0 24.0 24.0 24.0 24.0 24.0 24.0 24.0Units used in determining the generation resources in the Summer SummaryUnit NameUnit CodeCounty FuelForecastZoneYear InService2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Unit Capacities - SummerOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. Thislist includes MW available to the grid from private network (self-serve) units. It also includes distributed generationunits that have registered with ERCOT. Data without unit names are for private network units or are planned generation that isnot public.Rayburn 7 RAYBURN_RAYBURG7 Victoria Gas South200350.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0Rayburn 8 RAYBURN_RAYBURG8 Victoria Gas South200350.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0Rayburn 9 RAYBURN_RAYBURG9 Victoria Gas South200350.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0Rio Nogales 1RIONOG_CT1Guadalupe Gas South2002154.0 154.0 154.0 154.0 154.0 154.0 154.0 154.0 154.0 154.0Rio Nogales 2RIONOG_CT2Guadalupe Gas South2002154.0 154.0 154.0 154.0 154.0 154.0 154.0 154.0 154.0 154.0Rio Nogales 3RIONOG_CT3Guadalupe Gas South2002154.0 154.0 154.0 154.0 154.0 154.0 154.0 154.0 154.0 154.0Rio Nogales 4RIONOG_ST1Guadalupe Gas South2002323.0 323.0 323.0 323.0 323.0 323.0 323.0 323.0 323.0 323.0Sandhill Energy Center 5ASANDHSYD_SH_5A Travis Gas South2004155.0 155.0 155.0 155.0 155.0 155.0 155.0 155.0 155.0 155.0Sandhill Energy Center 5CSANDHSYD_SH_5C Travis Gas South2004145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0Sandhill Energy Center 1SANDHSYD_SH1Travis Gas South200145.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0Sandhill Energy Center 2SANDHSYD_SH2Travis Gas South200145.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0Sandhill Energy Center 3SANDHSYD_SH3Travis Gas South200145.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0Sandhill Energy Center 4SANDHSYD_SH4Travis Gas South200145.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0Sandhill Energy Center 6SANDHSYD_SH6Travis Gas South201045.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0Sandhill Energy Center 7SANDHSYD_SH7Travis Gas South201045.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0San Miguel 1SANMIGL_SANMIGG1 Atascosa Coal South1982391.0 391.0 391.0 391.0 391.0 391.0 391.0 391.0 391.0 391.0Stryker Creek 1SCSES_UNIT1ACherokee Gas North1958171.0 171.0 171.0 171.0 171.0 171.0 171.0 171.0 171.0 171.0Stryker Creek 2SCSES_UNIT2Cherokee Gas North1965502.0 502.0 502.0 502.0 502.0 502.0 502.0 502.0 502.0 502.0Sandow 5SD5SES_UNIT5Milam Coal South2010570.0 570.0 570.0 570.0 570.0 570.0 570.0 570.0 570.0 570.0Silas Ray 10SILASRAY_SILAS_10 Cameron Gas South200448.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Silas Ray 5SILASRAY_SILAS_5 Cameron Gas South195110.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0Silas Ray 6SILASRAY_SILAS_6 Cameron Gas South196120.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0Silas Ray 9SILASRAY_SILAS_9 Cameron Gas South199638.038.038.0 38.0 38.0 38.0 38.0 38.0 38.0 38.0San Jacinto SES 1SJS_SJS_G1Harris Gas Houston199581.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0San Jacinto SES 2SJS SJS G2HarrisGasHouston199581.081.081.081.081.081.081.081.081.081.0SanJacintoSES2SJS_SJS_G2HoustonSam Bertron 3SRB_SRB_G3Harris Gas Houston1959230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0Sam Bertron 4SRB_SRB_G4Harris Gas Houston1960230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0Sam Bertron T2SRB_SRBGT_2Harris Gas Houston196713.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0Greenville Engine PlantSTEAM_ENGINE_1 Hunt Gas North20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Greenville Engine PlantSTEAM_ENGINE_2 Hunt Gas North20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Greenville Engine PlantSTEAM_ENGINE_3 Hunt Gas North20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Powerlane Plant 2STEAM_STEAM_2Hunt Gas North196726.0 26.0 26.0 26.0 26.0 26.0 26.0 26.0 26.0 26.0Powerlane Plant 3STEAM_STEAM_3Hunt Gas North197841.0 41.0 41.0 41.0 41.0 41.0 41.0 41.0 41.0 41.0Powerlane Plant 1STEAM1A_STEAM_1 Hunt Gas North200920.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0South Texas 1STP_STP_G1Matagorda Nuclear South19881362.0 1362.0 1362.0 1362.0 1362.0 1362.0 1362.0 1362.0 1362.0 1362.0South Texas 2STP_STP_G2Matagorda Nuclear South19891362.0 1362.0 1362.0 1362.0 1362.0 1362.0 1362.0 1362.0 1362.0 1362.0Johnson County GenFacility 1TEN_CT1Johnson Gas North1997163.0 163.0 163.0 163.0 163.0 163.0 163.0 163.0 163.0 163.0Johnson County GenFacility 2TEN_STGJohnson Gas North1997106.0 106.0 106.0 106.0 106.0 106.0 106.0 106.0 106.0 106.0Texas Gulf SulphurTGF_TGFGT_1Wharton Gas Houston198570.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0T H Wharton G1THW_THWGT_1Harris Gas Houston196713.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0T H Wharton 31THW_THWGT31Harris Gas Houston197257.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 32THW_THWGT32Harris Gas Houston197257.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 33THW_THWGT33Harris Gas Houston197257.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 34THW_THWGT34Harris Gas Houston197257.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 41THW_THWGT41Harris Gas Houston197257.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 42THW_THWGT42Harris Gas Houston197257.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 43THW_THWGT43Harris Gas Houston197457.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 44THW_THWGT44Harris Gas Houston197457.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0Units used in determining the generation resources in the Summer SummaryUnit NameUnit CodeCounty FuelForecastZoneYear InService2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Unit Capacities - SummerOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. Thislist includes MW available to the grid from private network (self-serve) units. It also includes distributed generationunits that have registered with ERCOT. Data without unit names are for private network units or are planned generation that isnot public.T H Wharton 51THW_THWGT51Harris Gas Houston197557.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 52THW_THWGT52Harris Gas Houston197557.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 53THW_THWGT53Harris Gas Houston197557.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 54THW_THWGT54Harris Gas Houston197557.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 55THW_THWGT55Harris Gas Houston197557.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 56THW_THWGT56Harris Gas Houston197557.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 3THW_THWST_3Harris Gas Houston1974104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0T H Wharton 4THW_THWST_4Harris Gas Houston1974104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0Twin Oaks 1TNP_ONE_TNP_O_1 Robertson Coal North1990156.0 156.0 156.0 156.0 156.0 156.0 156.0 156.0 156.0 156.0Twin Oaks 2TNP_ONE_TNP_O_2 Robertson Coal North1991156.0 156.0 156.0 156.0 156.0 156.0 156.0 156.0 156.0 156.0Paris Energy Center 1TNSKA_GT1Lamar Gas North198976.0 76.0 76.0 76.0 76.0 76.0 76.0 76.0 76.0 76.0Paris Energy Center 2TNSKA_GT2Lamar Gas North198976.0 76.0 76.0 76.0 76.0 76.0 76.0 76.0 76.0 76.0Paris Energy Center 3TNSKA_STGLamar Gas North199087.0 87.0 87.0 87.0 87.0 87.0 87.0 87.0 87.0 87.0Baytown 1TRN_DG1Chambers Biomass Houston20033.9 3.9 3.9 3.9 3.9 3.9 3.9 3.9 3.9 3.9Trinidad 6TRSES_UNIT6Henderson Gas North1965226.0 226.0 226.0 226.0 226.0 226.0 226.0 226.0 226.0 226.0Texas City 1TXCTY_CTAGalveston Gas Houston2000100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0Texas City 2TXCTY_CTBGalveston Gas Houston200093.0 93.0 93.0 93.0 93.0 93.0 93.0 93.0 93.0 93.0Texas City 3TXCTY_CTCGalveston Gas Houston200093.0 93.0 93.0 93.0 93.0 93.0 93.0 93.0 93.0 93.0Texas City 4TXCTY_STGalveston Gas Houston2000128.0 128.0 128.0 128.0 128.0 128.0 128.0 128.0 128.0 128.0Victoria Power Station 5VICTORIA_VICTORG5 Victoria Gas South2009125.0 125.0 125.0 125.0 125.0 125.0 125.0 125.0 125.0 125.0Victoria Power Station 6VICTORIA_VICTORG6 Victoria Gas South2009160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0W A Parish 1WAP_WAP_G1Ft. Bend Gas Houston1958174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0W A Parish 2WAP_WAP_G2Ft. Bend Gas Houston1958174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0W A Parish 3WAP_WAP_G3Ft. Bend Gas Houston1961278.0 278.0 278.0 278.0 278.0 278.0 278.0 278.0 278.0 278.0W A Parish 4WAP WAP G4Ft. BendGasHouston1968552.0552.0552.0552.0552.0552.0552.0552.0552.0552.0WAParish4WAP_WAP_G4Ft.BendHoustonW A Parish 5WAP_WAP_G5Ft. Bend Coal Houston1977645.0 645.0 645.0 645.0 645.0 645.0 645.0 645.0 645.0 645.0W A Parish 6WAP_WAP_G6Ft. Bend Coal Houston1978650.0 650.0 650.0 650.0 650.0 650.0 650.0 650.0 650.0 650.0W A Parish 7WAP_WAP_G7Ft. Bend Coal Houston1980565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0W A Parish 8WAP_WAP_G8Ft. Bend Coal Houston1982610.0 610.0 610.0 610.0 610.0 610.0 610.0 610.0 610.0 610.0W A Parish T1WAP_WAPGT_1Ft. Bend Gas Houston196713.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0Wise-Tractebel Power Proj. 1WCPP_CT1Wise Gas North2004212.0 212.0 212.0 212.0 212.0 212.0 212.0 212.0 212.0 212.0Wise-Tractebel Power Proj. 2WCPP_CT2Wise Gas North2004212.0 212.0 212.0 212.0 212.0 212.0 212.0 212.0 212.0 212.0Wise-Tractebel Power Proj. 3WCPP_ST1Wise Gas North2004241.0 241.0 241.0 241.0 241.0 241.0 241.0 241.0 241.0 241.0Wichita Falls 1WFCOGEN_UNIT1Wichita Gas West198720.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0Wichita Falls 2WFCOGEN_UNIT2Wichita Gas West198720.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0Wichita Falls 3WFCOGEN_UNIT3Wichita Gas West198720.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0Wichita Falls 4WFCOGEN_UNIT4Wichita Gas West198717.0 17.0 17.0 17.0 17.0 17.0 17.0 17.0 17.0 17.0Wolf Hollow Power Proj. 1WHCCS_CT1Hood Gas North2002212.5 212.5 212.5 212.5 212.5 212.5 212.5 212.5 212.5 212.5Wolf Hollow Power Proj. 2WHCCS_CT2Hood Gas North2002212.5 212.5 212.5 212.5 212.5 212.5 212.5 212.5 212.5 212.5Wolf Hollow Power Proj. 3WHCCS_STGHood Gas North2002280.0 280.0 280.0 280.0 280.0 280.0 280.0 280.0 280.0 280.0Winchester Power Park 1WIPOPA_WPP_G1Fayette Gas South201044.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8Winchester Power Park 2WIPOPA_WPP_G2Fayette Gas South201044.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8Winchester Power Park 3WIPOPA_WPP_G3Fayette Gas South201044.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8Winchester Power Park 4WIPOPA_WPP_G4Fayette Gas South201044.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8Granite Shoals 1WIRTZ_WIRTZ_G1Burnet Hydro South195130.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0Granite Shoals 2WIRTZ_WIRTZ_G2Burnet Hydro South195130.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0Whitney 1WND_WHITNEY1Bosque Hydro North195315.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0Whitney 2WND_WHITNEY2Bosque Hydro North195315.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0Units used in determining the generation resources in the Summer SummaryUnit NameUnit CodeCounty FuelForecastZoneYear InService2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Unit Capacities - SummerOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. Thislist includes MW available to the grid from private network (self-serve) units. It also includes distributed generationunits that have registered with ERCOT. Data without unit names are for private network units or are planned generation that isnot public.Operational63,859 63,859 63,859 63,859 63,859 63,859 63,859 63,859 63,859 63,859Gas Houston12.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0Gas Houston74.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0Gas Houston531.1 531.1 531.1 531.1 531.1 531.1 531.1 531.1 531.1 531.1Gas Houston74.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0Gas Houston620.0 620.0 620.0 620.0 620.0 620.0 620.0 620.0 620.0 620.0Gas Houston300.0 300.0 300.0 300.0 300.0 300.0 300.0 300.0 300.0 300.0Gas Houston166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0Gas West17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5Gas South352.0 352.0 352.0 352.0 352.0 352.0 352.0 352.0 352.0 352.0Gas South5.0 5.0 8.0 8.0 8.0 8.0 8.0 8.0 8.0 8.0Gas Houston269.0 269.0 269.0 269.0 269.0 269.0 269.0 269.0 269.0 269.0Gas Houston280.0 280.0 280.0 280.0 280.0 280.0 280.0 280.0 280.0 280.0Gas Houston215.0 215.0 215.0 215.0 215.0 215.0 215.0 215.0 215.0 215.0Gas Houston0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Gas South0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Gas Houston70.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0Gas South50.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0Gas South400.0 400.0 400.0 400.0 400.0 400.0 400.0 400.0 400.0 400.0Gas South0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Gas Houston110.0 110.0 110.0 110.0 110.0 110.0 110.0 110.0 110.0 110.0Gas South25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0Gas South33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4 33.4GasHouston485.0485.0485.0485.0485.0485.0485.0485.0485.0485.0HoustonGas Houston325.0 325.0 325.0 325.0 325.0 325.0 325.0 325.0 325.0 325.0Coal South575.0 575.0 575.0 575.0 575.0 575.0 575.0 575.0 575.0 575.0Gas South3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0Gas Houston15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0Gas South15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0Gas Houston1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0Generation from Private Use Networks5,023.0 5,071.0 5,074.0 5,074.0 5,074.0 5,074.0 5,074.0 5,074.0 5,074.0 5,074.0RMR0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Eagle PassDC TieMaverick Other South36.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0EastDC TieFannin Other North600.0 600.0600.0 600.0 600.0 600.0 600.0 600.0 600.0 600.0Laredo VFTDC TieWebb Other South100.0 100.0100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0NorthDC TieWilbarger Other West220.0 220.0220.0 220.0 220.0 220.0 220.0 220.0 220.0 220.0SharylandDC TieHidalgo Other South150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0DC-Ties1,106.0 1,106.0 1,106.0 1,106.0 1,106.0 1,106.0 1,106.0 1,106.0 1,106.0 1,106.0Kiamichi Energy Facility 1CT101 KMCHI_1CT101Fannin Gas North2003153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0Kiamichi Energy Facility 1CT201 KMCHI_1CT201Fannin Gas North2003155.0 155.0 155.0 155.0 155.0 155.0 155.0 155.0 155.0 155.0Kiamichi Energy Facility 1STKMCHI_1STFannin Gas North2003315.0 315.0 315.0 315.0 315.0 315.0 315.0 315.0 315.0 315.0Kiamichi Energy Facility 2CT101 KMCHI_2CT101Fannin Gas North2003153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0Kiamichi Energy Facility 2CT201 KMCHI_2CT201Fannin Gas North2003155.0 155.0 155.0 155.0 155.0 155.0 155.0 155.0 155.0 155.0Kiamichi Energy Facility 2STKMCHI_2STFannin Gas North2003315.0 315.0 315.0 315.0 315.0 315.0 315.0 315.0 315.0 315.0Units used in determining the generation resources in the Summer SummaryUnit NameUnit CodeCounty FuelForecastZoneYear InService2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Unit Capacities - SummerOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. Thislist includes MW available to the grid from private network (self-serve) units. It also includes distributed generationunits that have registered with ERCOT. Data without unit names are for private network units or are planned generation that isnot public.Tenaska-Frontier 1 FTR_FTR_G1 Grimes Gas North2000160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0Tenaska-Frontier 2 FTR_FTR_G2 Grimes Gas North2000160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0Tenaska-Frontier 3 FTR_FTR_G3 Grimes Gas North2000160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0Tenaska-Frontier 4 FTR_FTR_G4 Grimes Gas North2000390.0 390.0 390.0 390.0 390.0 390.0 390.0 390.0 390.0 390.0Tenaska-Gateway 1 TGCCS_CT1 Rusk Gas North2001156.0 156.0 156.0 156.0 156.0 156.0 156.0 156.0 156.0 156.0Tenaska-Gateway 2 TGCCS_CT2 Rusk Gas North2001135.0 135.0 135.0 135.0 135.0 135.0 135.0 135.0 135.0 135.0Tenaska-Gateway 3 TGCCS_CT3 Rusk Gas North2001153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0 153.0Tenaska-Gateway 4TGCCS_UNIT4Rusk Gas North2001402.0 402.0 402.0 402.0 402.0 402.0 402.0 402.0 402.0 402.0Switchable Resources2,962.0 2,962.0 2,962.0 2,962.0 2,962.0 2,962.0 2,962.0 2,962.0 2,962.0 2,962.0Kunitz WindKUNITZ_WIND_LGE Culberson Wind West199539.8 39.8 39.8 39.8 39.8 39.8 39.8 39.8 39.8 39.8Texas Big SpringSGMTN_SIGNALMT Howard Wind West199934.3 34.3 34.3 34.3 34.3 34.3 34.3 34.3 34.3 34.3West Texas Wind EnergySW_MESA_SW_MESA Upton Wind West199974.2 74.2 74.2 74.2 74.2 74.2 74.2 74.2 74.2 74.2Indian Mesa Wind FarmINDNNWP_INDNNWP Pecos Wind West200182.5 82.5 82.5 82.5 82.5 82.5 82.5 82.5 82.5 82.5King Mountain NEKING_NE_KINGNEUpton Wind West200179.3 79.3 79.3 79.3 79.3 79.3 79.3 79.3 79.3 79.3King Mountain NWKING_NW_KINGNW Upton Wind West200179.3 79.3 79.3 79.3 79.3 79.3 79.3 79.3 79.3 79.3King Mountain SEKING_SE_KINGSEUpton Wind West200140.3 40.3 40.3 40.3 40.3 40.3 40.3 40.3 40.3 40.3King Mountain SWKING_SW_KINGSW Upton Wind West200179.3 79.3 79.3 79.3 79.3 79.3 79.3 79.3 79.3 79.3Pecos Wind (Woodward 1)WOODWRD1_WOODWRD1 Pecos Wind West200182.5 82.5 82.5 82.5 82.5 82.5 82.5 82.5 82.5 82.5Pecos Wind (Woodward 2)WOODWRD2_WOODWRD2 Pecos Wind West200177.2 77.2 77.2 77.2 77.2 77.2 77.2 77.2 77.2 77.2Trent Wind FarmTRENT_TRENTNolan Wind West2001150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0Desert Sky Wind Farm 1INDNENR_INDNENR Pecos Wind West200284.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0Desert Sky Wind Farm 2INDNENR_INDNENR_2 Pecos Wind West200276.5 76.5 76.5 76.5 76.5 76.5 76.5 76.5 76.5 76.5Green Mountain Energy 1BRAZ_WND_WND1 Scurry Wind West200399.0 99.0 99.0 99.0 99.0 99.0 99.0 99.0 99.0 99.0Green Mountain Energy 2BRAZ WND WND2ScurryWindWest200361.061.061.061.061.061.061.061.061.061.0GreenMountainEnergy2BRAZ_WND_WND2Sweetwater Wind 1SWEETWND_WND1 Nolan Wind West200336.6 36.6 36.6 36.6 36.6 36.6 36.6 36.6 36.6 36.6Callahan WindCALLAHAN_WND1Callahan Wind West2004114.0 114.0 114.0 114.0 114.0 114.0 114.0 114.0 114.0 114.0Sweetwater Wind 3SWEETWN2_WND2 Nolan Wind West200497.5 97.5 97.5 97.5 97.5 97.5 97.5 97.5 97.5 97.5Horse Hollow Wind 1H_HOLLOW_WND1 Taylor Wind West2005213.0 213.0 213.0 213.0 213.0 213.0 213.0 213.0 213.0 213.0Sweetwater Wind 4SWEETWN3_WND3 Nolan Wind West2005129.0 129.0 129.0 129.0 129.0 129.0 129.0 129.0 129.0 129.0Buffalo Gap Wind Farm 1BUFF_GAP_UNIT1Taylor Wind West2006120.6 120.6 120.6 120.6 120.6 120.6 120.6 120.6 120.6 120.6Horse Hollow Wind 2HHOLLOW2_WIND1 Taylor Wind West2006184.0 184.0 184.0 184.0 184.0 184.0 184.0 184.0 184.0 184.0Horse Hollow Wind 3HHOLLOW3_WND_1 Taylor Wind West2006223.5 223.5 223.5 223.5 223.5 223.5 223.5 223.5 223.5 223.5Horse Hollow Wind 4HHOLLOW4_WND1 Taylor Wind West2006115.0 115.0 115.0 115.0 115.0 115.0 115.0 115.0 115.0 115.0Mesquite WindLNCRK_G83Shackelford Wind West2006200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0Red CanyonRDCANYON_RDCNY1 Borden Wind West200684.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0Sweetwater Wind 2SWEETWN2_WND24 Nolan Wind West200615.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9Barton Chapel WindBRTSW_BCW1Jack Wind North2007120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0Buffalo Gap Wind Farm 2BUFF_GAP_UNIT2Taylor Wind West2007232.5 232.5 232.5 232.5 232.5 232.5 232.5 232.5 232.5 232.5Camp Springs 1CSEC_CSECG1Scurry Wind West2007134.4 134.4 134.4 134.4 134.4 134.4 134.4 134.4 134.4 134.4Camp Springs 2CSEC_CSECG2Scurry Wind West2007123.6 123.6 123.6 123.6 123.6 123.6 123.6 123.6 123.6 123.6Capricorn Ridge Wind 1CAPRIDGE_CR1Sterling Wind West2007214.5 214.5 214.5 214.5 214.5 214.5 214.5 214.5 214.5 214.5Capricorn Ridge Wind 3CAPRIDGE_CR2Sterling Wind West2007149.5 149.5 149.5 149.5 149.5 149.5 149.5 149.5 149.5 149.5Forest Creek Wind FarmMCDLD_FCW1Glasscock Wind West2007124.2 124.2 124.2 124.2 124.2 124.2 124.2 124.2 124.2 124.2Post Oak Wind 1LNCRK2_G871Shackelford Wind West2007100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0Post Oak Wind 2LNCRK2_G872Shackelford Wind West2007100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0Snyder Wind FarmENAS_ENA1Scurry Wind West200763.0 63.0 63.0 63.0 63.0 63.0 63.0 63.0 63.0 63.0Sweetwater Wind 5SWEETWN4_WND5 Nolan Wind West200779.2 79.2 79.2 79.2 79.2 79.2 79.2 79.2 79.2 79.2Units used in determining the generation resources in the Summer SummaryUnit NameUnit CodeCounty FuelForecastZoneYear InService2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Unit Capacities - SummerOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. Thislist includes MW available to the grid from private network (self-serve) units. It also includes distributed generationunits that have registered with ERCOT. Data without unit names are for private network units or are planned generation that isnot public.Sweetwater Wind 6SWEETWN4_WND4B Nolan Wind West2007103.7 103.7 103.7 103.7 103.7 103.7 103.7 103.7 103.7 103.7Sweetwater Wind 7SWEETWN4_WND4A Nolan Wind West2007117.8 117.8 117.8 117.8 117.8 117.8 117.8 117.8 117.8 117.8Whirlwind EnergyWEC_WECG1Floyd Wind West200760.0 60.0 60.0 60.0 60.0 60.0 60.0 60.0 60.0 60.0Wolfe FlatsDG_TURL_UNIT1HallWind West200710.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0Buffalo Gap Wind Farm 3BUFF_GAP_UNIT3Taylor Wind West2008170.2 170.2 170.2 170.2 170.2 170.2 170.2 170.2 170.2 170.2Capricorn Ridge Wind 2CAPRIDGE_CR3Sterling Wind West2008186.0 186.0 186.0 186.0 186.0 186.0 186.0 186.0 186.0 186.0Capricorn Ridge Wind 4CAPRIDG4_CR4Sterling Wind West2008112.5 112.5 112.5 112.5 112.5 112.5 112.5 112.5 112.5 112.5Champion Wind FarmCHAMPION_UNIT1Nolan Wind West2008126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5Elbow Creek Wind ProjectELB_ELBCREEKHoward Wind West2008122.0 122.0 122.0 122.0 122.0 122.0 122.0 122.0 122.0 122.0Goat WindGOAT_GOATWIND Sterling Wind West200880.0 80.0 80.0 80.0 80.0 80.0 80.0 80.0 80.0 80.0Hackberry Wind FarmHWF_HWFG1Shackelford Wind West2008166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0Inadale WindINDL_INADALE1Nolan Wind West2008197.0 197.0 197.0 197.0 197.0 197.0 197.0 197.0 197.0 197.0McAdoo Wind FarmMWEC_G1Dickens Wind West2008150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0Ocotillo Wind FarmOWF_OWFHoward Wind West200858.8 58.8 58.8 58.8 58.8 58.8 58.8 58.8 58.8 58.8Panther Creek 1PC_NORTH_PANTHER1 Howard Wind West2008142.5 142.5 142.5 142.5 142.5 142.5 142.5 142.5 142.5 142.5Panther Creek 2PC_SOUTH_PANTHER2 Howard Wind West2008115.5 115.5 115.5 115.5 115.5 115.5 115.5 115.5 115.5 115.5Pyron Wind FarmPYR_PYRON1Scurry Wind West2008249.0 249.0 249.0 249.0 249.0 249.0 249.0 249.0 249.0 249.0Roscoe Wind FarmTKWSW1_ROSCOE Nolan Wind West2008209.0 209.0 209.0 209.0 209.0 209.0 209.0 209.0 209.0 209.0Sand Bluff Wind FarmMCDLD_SBW1Glasscock Wind West200890.0 90.0 90.0 90.0 90.0 90.0 90.0 90.0 90.0 90.0Sherbino IKEO_KEO_SM1Pecos Wind West2008150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0Silver StarFLTCK_SSIEastland Wind North200860.0 60.0 60.0 60.0 60.0 60.0 60.0 60.0 60.0 60.0South Trent Wind FarmSTWF_T1Nolan Wind West2008101.2 101.2 101.2 101.2 101.2 101.2 101.2 101.2 101.2 101.2Stanton Wind EnergySWEC_G1Martin Wind West2008123.6 123.6 123.6 123.6 123.6 123.6 123.6 123.6 123.6 123.6TSTC West Texas WindDG_ROSC2_1UNIT Nolan Wind West20082.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0Turkey Track Wind Energy CenterTTWEC G1NolanWindWest2008175.0175.0175.0175.0175.0175.0175.0175.0175.0175.0TurkeyTrackWindEnergyCenterTTWEC_G1Wolfe RidgeWHTTAIL_WR1Cooke Wind North2008112.5 112.5 112.5 112.5 112.5 112.5 112.5 112.5 112.5 112.5Bull Creek Wind PlantBULLCRK_WND1Borden Wind West200989.0 89.0 89.0 89.0 89.0 89.0 89.0 89.0 89.0 89.0Bull Creek Wind PlantBULLCRK_WND2Borden Wind West200991.0 91.0 91.0 91.0 91.0 91.0 91.0 91.0 91.0 91.0Horse Hollow Wind 1HHGT_HHOLLOW1 Kendall Wind South20090.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Horse Hollow Wind 2HHGT_HHOLLOW2 Kendall Wind South20090.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Horse Hollow Wind 3HHGT_HHOLLOW3 Kendall Wind South20090.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Horse Hollow Wind 4HHGT_HHOLLOW4 Kendall Wind South20090.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Horse Hollow Wind CallahanHHGT_CALLAHANKendall Wind South20090.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Langford Wind PowerLGD_LANGFORDTom Green Wind West2009150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0Loraine Windpark ILONEWOLF_G1Mitchell Wind West200950.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0Loraine Windpark IILONEWOLF_G2Mitchell Wind West200951.0 51.0 51.0 51.0 51.0 51.0 51.0 51.0 51.0 51.0Loraine Windpark IIILONEWOLF_G3Mitchell Wind West201126.0 26.0 26.0 26.0 26.0 26.0 26.0 26.0 26.0 26.0Loraine Windpark IVLONEWOLF_G4Mitchell Wind West201124.0 24.0 24.0 24.0 24.0 24.0 24.0 24.0 24.0 24.0Notrees-1NWF_NWF1Winkler Wind West2009152.6 152.6 152.6 152.6 152.6 152.6 152.6 152.6 152.6 152.6Panther Creek 3PC_SOUTH_PANTHER3 Howard Wind West2009199.5 199.5 199.5 199.5 199.5 199.5 199.5 199.5 199.5 199.5Papalote Creek Wind FarmPAP1_PAP1San Patricio Wind South2009179.9 179.9 179.9 179.9 179.9 179.9 179.9 179.9 179.9 179.9Penascal WindPENA_UNIT1Kenedy Wind South2009160.8 160.8 160.8 160.8 160.8 160.8 160.8 160.8 160.8 160.8Penascal WindPENA_UNIT2Kenedy Wind South2009141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6Cedro Hill WindCEDROHIL_CHW1Webb Wind South2010150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0Delaware Mountain Wind Farm KUNITZ_WIND_NWP Culberson Wind West201028.5 28.5 28.5 28.5 28.5 28.5 28.5 28.5 28.5 28.5Goat Wind 2GOAT_GOATWIN2Sterling Wind West201069.6 69.6 69.6 69.6 69.6 69.6 69.6 69.6 69.6 69.6Gulf Wind ITGW_T1Kenedy Wind South2010141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6Gulf Wind IITGW_T2Kenedy Wind South2010141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6Units used in determining the generation resources in the Summer SummaryUnit NameUnit CodeCounty FuelForecastZoneYear InService2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Unit Capacities - SummerOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. Thislist includes MW available to the grid from private network (self-serve) units. It also includes distributed generationunits that have registered with ERCOT. Data without unit names are for private network units or are planned generation that isnot public.Papalote Creek WindCOTTON_PAP2San Patricio Wind South2010200.1 200.1 200.1 200.1 200.1 200.1 200.1 200.1 200.1 200.1Penascal WindPENA_UNIT3Kenedy Wind South2010100.8 100.8 100.8 100.8 100.8 100.8 100.8 100.8 100.8 100.8WIND9,452 9,452 9,452 9,452 9,452 9,452 9,452 9,452 9,452 9,452Atkins 3ATKINS_ATKINSG3 Brazos Gas North1954-12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0Atkins 4ATKINS_ATKINSG4 Brazos Gas North1958-22.0 22.0 22.0 22.0 22.0 22.0 22.0 22.0 22.0Atkins 5ATKINS_ATKINSG5 Brazos Gas North1965-25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0Atkins 6ATKINS_ATKINSG6 Brazos Gas North1969-50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0AES DeepwaterAPD_APD_G1Harris Other Houston1986-138.0 138.0 138.0 138.0 138.0 138.0 138.0 138.0 138.0C E Newman 5NEWMAN_NEWMA_5 Dallas Gas North1963-37.0 37.0 37.0 37.0 37.0 37.0 37.0 37.0 37.0Leon Creek 3LEON_CRK_LCP3G3 Bexar Gas South1953-56.0 56.0 56.0 56.0 56.0 56.0 56.0 56.0 56.0Leon Creek 4LEON_CRK_LCP4G4 Bexar Gas South1959-88.0 88.0 88.0 88.0 88.0 88.0 88.0 88.0 88.0North Texas 1NTX_NTX_1Parker Gas North1958-18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0North Texas 2NTX_NTX_2Parker Gas North1958-18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0North Texas 3NTX_NTX_3Parker Gas North1963-39.0 39.0 39.0 39.0 39.0 39.0 39.0 39.0 39.0Permian Basin 6PBSES_UNIT6Ward Gas West2009-515.0 515.0 515.0 515.0 515.0 515.0 515.0 515.0 515.0Sam Bertron 1SRB_SRB_G1Harris Gas Houston1958-174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0Sam Bertron 2SRB_SRB_G2Harris Gas Houston1956-174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0Spencer 4SPNCER_SPNCE_4 Denton Gas North1966-61.0 61.0 61.0 61.0 61.0 61.0 61.0 61.0 61.0Spencer 5SPNCER_SPNCE_5 Denton Gas North1973-61.0 61.0 61.0 61.0 61.0 61.0 61.0 61.0 61.0Valley 1VLSES_UNIT1Fannin Gas North1962-174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0Valley 2VLSES_UNIT2Fannin Gas North1967-520.0 520.0 520.0 520.0 520.0 520.0 520.0 520.0 520.0Valley 3VLSES_UNIT3Fannin Gas North1971-375.0 375.0 375.0 375.0 375.0 375.0 375.0 375.0 375.0Mothballed Resources-2,557.0 2,557.0 2,557.0 2,557.0 2,557.0 2,557.0 2,557.0 2,557.0 2,557.0Nacogdoches Project09INR0007Nacogdoches Biomass-100.0100.0100.0100.0100.0100.0 100.0 100.0 100.0Sandy Creek 109INR0001McLennan Coal-925.0925.0925.0925.0925.0925.0 925.0 925.0 925.0CFB Power Plant Units 11&1209INR0029Calhoun Coal260.0260.0260.0260.0260.0260.0260.0 260.0 260.0 260.0Coleto Creek Unit 214INR0002Goliad Coal------660.0660.0 660.0 660.0Panda Temple Power10INR0020bBellGas----780.0780.0780.0 780.0 780.0 780.0Panda Temple Power10INR0020aBellGas---780.0780.0780.0780.0 780.0 780.0 780.0Jack County 210INR0010Jack Gas-565.0565.0565.0565.0565.0565.0 565.0 565.0 565.0Pondera King Power Project10INR0022Harris Gas----1,380.01,380.01,380.0 1,380.0 1,380.0 1,380.0Las Brisas Energy Center12INR0016aNueces Other-----620.0620.0 620.0 620.0 620.0Las Brisas Energy Center12INR0016bNueces Other------620.0620.0 620.0 620.0RRE Austin Solar11INR0086Travis Solar-60.060.060.060.060.060.0 60.0 60.0 60.0FRV AE Solar10INR0082Travis Solar-30.030.030.030.030.030.0 30.0 30.0 30.0New Units with Signed IA and Air Permit260.01,940.01,940.02,720.04,880.05,500.06,780.0 6,780.0 6,780.0 6,780.0Gunsight Mountain08INR0018Howard Wind--120.0120.0120.0120.0120.0 120.0 120.0 120.0Los Vientos11INR0033Cameron Wind--400.0400.0400.0400.0400.0 400.0 400.0 400.0Archer-Young08INR0062Young Wind-250.0250.0250.0250.0250.0250.0 250.0 250.0 250.0Penascal Wind Farm 306INR0022cKenedy Wind---202.0202.0202.0202.0 202.0 202.0 202.0Sherbino Mesa Wind Farm 206INR0012bPecos Wind150.0150.0150.0150.0150.0150.0150.0 150.0 150.0 150.0Magic Valley Wind Project10INR0060Willacy Wind-202.0202.0202.0202.0202.0202.0202.0 202.0 202.0WKN Mozart09INR0061Kent Wind--30.030.030.030.030.0 30.0 30.0 30.0Senate Wind Project08INR0011Jack Wind-150.0150.0150.0150.0150.0150.0 150.0 150.0 150.0Units used in determining the generation resources in the Summer SummaryUnit NameUnit CodeCounty FuelForecastZoneYear InService2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Unit Capacities - SummerOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. Thislist includes MW available to the grid from private network (self-serve) units. It also includes distributed generationunits that have registered with ERCOT. Data without unit names are for private network units or are planned generation that isnot public.New Wind Generation150.0752.01,302.01,504.01,504.01,504.01,504.0 1,504.0 1,504.0 1,504.0Pampa Energy Center07INR0004Gray Coal-165.0165.0165.0165.0165.0165.0 165.0 165.0 165.0White Stallion Energy Center14INR0005Matagorda Coal---1,200.01,200.01,200.01,200.0 1,200.0 1,200.0 1,200.0Comanche Peak 3 and 415INR0002Somervel Nuclear------ --3,200.03,200.0STP 3 and 415INR0008Matagorda Nuclear-----2,700.02,700.0 2,700.0 2,700.0 2,700.0Potential Public Non-Wind Resources-165.0165.0 1,365.01,365.04,065.04,065.0 4,065.0 7,265.0 7,265.0Throckmorton Wind Farm12INR0003Throckmorton Wind-400.0400.0400.0400.0400.0400.0 400.0 400.0 400.0Buffalo Gap 4 and 508INR0065Nolan Wind-465.0465.0465.0465.0465.0465.0 465.0 465.0 465.02W Whatley Phase 111INR0084Ector Wind-45.045.045.045.045.045.045.0 45.0 45.0B&B Panhandle Wind09INR0024Carson Wind-1,001.01,001.01,001.01,001.01,001.01,001.0 1,001.0 1,001.0 1,001.0Fort Concho Wind Farm12INR0004Tom Green Wind-400.0400.0400.0400.0400.0400.0 400.0 400.0 400.0Scurry County Wind III09INR0037Scurry Wind-350.0350.0350.0350.0350.0350.0 350.0 350.0 350.0M Bar Wind08INR0038Andrews Wind-194.0194.0194.0194.0194.0194.0 194.0 194.0 194.0Gatesville Wind Farm09INR0034Coryell Wind-200.0200.0200.0200.0200.0200.0 200.0 200.0 200.0Pistol Hill Energy Center08INR0025Ector Wind-300.0300.0300.0300.0300.0300.0 300.0 300.0 300.02W Whatley Phase 212INR0043Ector Wind--290.0290.0290.0290.0290.0 290.0 290.0 290.0Potential Public Wind Resources-3,355.03,645.03,645.03,645.03,645.03,645.0 3,645.0 3,645.0 3,645.011INR0037Smith Biomass-50.050.050.050.050.050.050.0 50.0 50.014INR0003Nolan Coal---850.0850.0850.0850.0 850.0 850.0 850.011INR0075Fort Bend Coal-15.015.015.015.015.015.0 15.0 15.0 15.010INR0032Navarro Gas-775.0775.0775.0775.0775.0775.0 775.0 775.0 775.010INR0029HoodGas-810.0810.0810.0810.0810.0810.0810.0810.0810.010INR002911INR0040 Freestone Gas -640.0640.0640.0640.0640.0640.0 640.0 640.0 640.011INR0006Lamar Gas-579.0579.0579.0579.0579.0579.0 579.0 579.0 579.009INR0031Ector Gas-275.0275.0275.0275.0275.0275.0 275.0 275.0 275.009INR0050Fannin Gas-1,200.01,200.01,200.01,200.01,200.01,200.0 1,200.0 1,200.0 1,200.012INR0007Lamar Gas-296.0296.0296.0296.0296.0296.0 296.0 296.0 296.010INR0021Grayson Gas-646.0646.0646.0646.0646.0646.0 646.0 646.0 646.010INR0018Madison Gas-550.0550.0550.0550.0550.0550.0 550.0 550.0 550.013INR0021Llano Gas----600.0600.0600.0 600.0 600.0 600.013INR0028Hale Gas---392.0392.0392.0392.0 392.0 392.0 392.013INR0023Ector Gas--240.0240.0240.0240.0240.0 240.0 240.0 240.011INR0049Wharton Gas-275.0275.0275.0275.0275.0275.0 275.0 275.0 275.011INR0071Harris Gas-7.07.07.07.07.07.0 7.0 7.0 7.016INR0002Brazoria Other------700.0700.0 700.0 700.010INR0089Harris Other-40.040.040.040.040.040.0 40.0 40.0 40.010INR0080Presidio Solar-144.0144.0144.0144.0144.0144.0 144.0 144.0 144.010INR0085Ector Solar-40.040.040.040.040.040.0 40.0 40.0 40.011INR0094Kent Solar-100.0100.0100.0100.0100.0100.0 100.0 100.0 100.012INR0057Ector Solar--40.040.040.040.040.0 40.0 40.0 40.011INR0090Howard Solar-60.060.060.060.060.060.0 60.0 60.0 60.015INR0011bBorden Solar-----38.038.0 38.0 38.0 38.011INR0070Reeves Solar-50.050.050.050.050.050.0 50.0 50.0 50.011INR0061Presidio Solar-90.090.090.090.090.090.0 90.0 90.0 90.011INR0060Tom Green Solar-90.090.090.090.090.090.0 90.0 90.0 90.0Units used in determining the generation resources in the Summer SummaryUnit NameUnit CodeCounty FuelForecastZoneYear InService2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Unit Capacities - SummerOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. Thislist includes MW available to the grid from private network (self-serve) units. It also includes distributed generationunits that have registered with ERCOT. Data without unit names are for private network units or are planned generation that isnot public.11INR0058 Pecos Solar -135.0135.0135.0135.0135.0135.0 135.0 135.0 135.0Potential Non-Public Non-Wind Resources-6,867.07,147.08,389.08,989.09,027.09,727.0 9,727.0 9,727.0 9,727.007INR0013Coke Wind-200.0200.0200.0200.0200.0200.0 200.0 200.0 200.008INR0019aGray Wind---250.0250.0250.0250.0 250.0 250.0 250.008INR0019bGray Wind---250.0250.0250.0250.0 250.0 250.0 250.008INR0019cGray Wind---250.0250.0250.0250.0 250.0 250.0 250.008INR0020Eastland Wind-200.0200.0200.0200.0200.0200.0 200.0 200.0 200.008INR0031Childress Wind-100.0100.0100.0100.0100.0100.0 100.0 100.0 100.008INR0041Coke Wind--200.0200.0200.0200.0200.0200.0200.0 200.008INR0042Coke Wind--200.0200.0200.0200.0200.0 200.0 200.0 200.008INR0049Clay Wind--50.050.050.050.050.0 50.0 50.0 50.009INR0025Concho Wind--180.0180.0180.0180.0180.0 180.0 180.0 180.009INR0041Mitchell Wind--300.0300.0300.0300.0300.0 300.0 300.0 300.009INR0048Jack Wind-100.0100.0100.0100.0100.0100.0 100.0 100.0 100.009INR0051Borden Wind--249.0249.0249.0249.0249.0 249.0 249.0 249.009INR0054Stonewall Wind-148.5148.5148.5148.5148.5148.5 148.5 148.5 148.509INR0058Howard Wind--250.0250.0250.0250.0250.0 250.0 250.0 250.009INR0073Scurry Wind---200.0200.0200.0200.0 200.0 200.0200.009INR0074Motley Wind-70.070.070.070.070.070.0 70.0 70.0 70.009INR0077Reagan Wind---500.0500.0500.0500.0 500.0 500.0 500.010INR0008Pecos Wind-500.0500.0500.0500.0500.0500.0 500.0 500.0 500.010INR0009Castro Wind---300.0300.0300.0300.0 300.0 300.0 300.010INR0013Upton Wind-400.0400.0400.0400.0400.0400.0 400.0 400.0 400.010INR0015MitchellWind-- -350.0350.0350.0350.0350.0350.0350.010INR0015Mitchell10INR0016 Childress Wind -150.0150.0150.0150.0150.0150.0 150.0 150.0 150.010INR0019Deaf Smith Wind-609.0609.0609.0609.0609.0609.0 609.0 609.0 609.010INR0023Haskell Wind-386.0386.0386.0386.0386.0386.0 386.0 386.0 386.010INR0024Briscoe Wind--2,940.02,940.02,940.02,940.02,940.0 2,940.0 2,940.0 2,940.010INR0033Armstrong Wind-399.0399.0399.0399.0399.0399.0 399.0 399.0 399.010INR0041Floyd Wind-135.0135.0135.0135.0135.0135.0 135.0 135.0 135.010INR0042Mason Wind-170.0170.0170.0170.0170.0170.0 170.0 170.0 170.010INR0048Hardeman Wind-1,000.01,000.01,000.01,000.01,000.01,000.0 1,000.0 1,000.0 1,000.010INR0051Brazoria Wind-200.0200.0200.0200.0200.0200.0 200.0 200.0 200.010INR0052aKnox Wind-21.021.021.021.021.021.0 21.0 21.0 21.010INR0054Palo Pinto Wind-36.036.036.036.036.036.0 36.0 36.0 36.010INR0056Borden Wind--249.0249.0249.0249.0249.0 249.0 249.0 249.010INR0062aPecos Wind-80.080.080.080.080.080.0 80.0 80.0 80.010INR0062bPecos Wind--220.0220.0220.0220.0220.0 220.0 220.0 220.010INR0077Callahan Wind--101.0101.0101.0101.0101.0 101.0 101.0 101.010INR0079Nolan Wind-60.060.060.060.060.060.0 60.0 60.0 60.010INR0081aClay Wind-30.430.430.430.430.430.4 30.4 30.4 30.410INR0081bClay Wind-19.219.219.219.219.219.2 19.2 19.2 19.211INR0013Mills Wind---150.0150.0150.0150.0 150.0 150.0 150.011INR0019Upton Wind-200.0200.0200.0200.0200.0200.0 200.0 200.0 200.011INR0025Crockett Wind-400.0400.0400.0400.0400.0400.0 400.0 400.0 400.011INR0029Throckmorton Wind-200.0200.0200.0200.0200.0200.0 200.0 200.0 200.011INR0039Starr Wind-201.0201.0201.0201.0201.0201.0 201.0 201.0 201.0Units used in determining the generation resources in the Summer SummaryUnit NameUnit CodeCounty FuelForecastZoneYear InService2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Unit Capacities - SummerOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. Thislist includes MW available to the grid from private network (self-serve) units. It also includes distributed generationunits that have registered with ERCOT. Data without unit names are for private network units or are planned generation that isnot public.11INR0043 Coke Wind -300.0300.0300.0300.0300.0300.0 300.0 300.0 300.011INR0047Deaf Smith Wind-600.0600.0600.0600.0600.0600.0 600.0 600.0 600.011INR0050Crosby Wind-149.0149.0149.0149.0149.0149.0 149.0 149.0 149.011INR0054San Patricio Wind-161.0161.0161.0161.0161.0161.0 161.0 161.0 161.011INR0057Cameron Wind-165.0165.0165.0165.0165.0165.0 165.0 165.0 165.011INR0062Nueces Wind-149.0149.0149.0149.0149.0149.0 149.0 149.0 149.011INR0065Nueces Wind-240.0240.0240.0240.0240.0240.0 240.0 240.0 240.011INR0067Cameron Wind--78.078.078.078.078.0 78.0 78.0 78.011INR0076Archer Wind-94.094.094.094.094.094.0 94.094.094.011INR0079aClay Wind-200.0200.0200.0200.0200.0200.0 200.0 200.0 200.011INR0081Live Oak Wind--72.072.072.072.072.0 72.0 72.0 72.011INR0082AVal Verde Wind---50.050.050.050.0 50.0 50.0 50.011INR0082BVal Verde Wind--150.0150.0150.0150.0150.0 150.0 150.0 150.011INR0083ACrockett Wind---50.050.050.050.0 50.0 50.0 50.011INR0083BCrockett Wind--100.0100.0100.0100.0100.0 100.0 100.0 100.011INR0085Nolan Wind-106.0106.0106.0106.0106.0106.0 106.0 106.0 106.011INR0091Webb Wind-92.092.092.092.092.092.0 92.0 92.0 92.012INR0002aBriscoe Wind---200.0200.0200.0200.0 200.0 200.0 200.012INR0002bBriscoe Wind----200.0200.0200.0 200.0 200.0 200.012INR0002cBriscoe Wind-----350.0350.0 350.0 350.0 350.012INR0005Floyd Wind--1,100.01,100.01,100.01,100.01,100.0 1,100.0 1,100.0 1,100.012INR0018Gray Wind--500.0500.0500.0500.0500.0 500.0 500.0 500.012INR0026Randall Wind--400.0400.0400.0400.0400.0 400.0 400.0 400.012INR0027Gray Wind--200.0200.0200.0200.0200.0 200.0 200.0 200.012INR0029SwisherWind- -500.0500.0500.0500.0500.0500.0500.0500.012INR0029Swisher12INR0033 Motley Wind -150.0150.0150.0150.0150.0150.0 150.0 150.0 150.012INR0034Borden Wind--342.0342.0342.0342.0342.0 342.0 342.0 342.012INR0035Nueces Wind--249.0249.0249.0249.0249.0 249.0 249.0 249.012INR0042Deaf Smith Wind-400.0400.0400.0400.0400.0400.0 400.0 400.0 400.012INR0045Kleberg Wind-135.0135.0135.0135.0135.0135.0 135.0 135.0 135.012INR0053Crockett Wind-615.0615.0615.0615.0615.0615.0 615.0 615.0 615.012INR0072Kinney Wind--100.0100.0100.0100.0100.0 100.0 100.0 100.012INR0075Wilbarger Wind-499.0499.0499.0499.0499.0499.0 499.0 499.0 499.013INR0004Deaf Smith Wind---500.0500.0500.0500.0 500.0 500.0 500.013INR0005Carson Wind---600.0600.0600.0600.0 600.0 600.0 600.013INR0006Gray Wind---750.0750.0750.0750.0 750.0 750.0 750.013INR0007Pecos Wind---200.0200.0200.0200.0 200.0 200.0 200.013INR0010aParmer Wind--200.0200.0200.0200.0200.0 200.0 200.0 200.013INR0010bParmer Wind---500.0500.0500.0500.0 500.0 500.0 500.013INR0010cParmer Wind----500.0500.0500.0 500.0 500.0 500.013INR0016Deaf Smith Wind---250.5250.5250.5250.5 250.5 250.5 250.513INR0017Childress Wind---200.0200.0200.0200.0 200.0 200.0 200.013INR0020aGlasscock Wind--200.0200.0200.0200.0200.0 200.0 200.0 200.013INR0020bGlasscock Wind---150.0150.0150.0150.0 150.0 150.0 150.013INR0025Randall Wind---150.0150.0150.0150.0 150.0 150.0 150.013INR0026Oldham Wind---201.0201.0201.0201.0 201.0 201.0 201.013INR0036Hidalgo Wind--200.0200.0200.0200.0200.0 200.0 200.0 200.014INR0001Pecos Wind----500.0500.0500.0 500.0 500.0 500.0Units used in determining the generation resources in the Summer SummaryUnit NameUnit CodeCounty FuelForecastZoneYear InService2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Unit Capacities - SummerOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. Thislist includes MW available to the grid from private network (self-serve) units. It also includes distributed generationunits that have registered with ERCOT. Data without unit names are for private network units or are planned generation that isnot public.14INR0006 Floyd Wind ----151.0151.0151.0 151.0 151.0 151.015INR0011aBorden Wind-----112.0112.0 112.0 112.0 112.0Potential Non-Public Wind Resources-10,070.119,400.125,451.626,802.627,264.627,264.6 27,264.6 27,264.6 27,264.6Excluded Resources, per notification from developerCobisa-Greenville06INR0006Hunt Gas---1,792.01,792.01,792.01,792.0 1,792.0 1,792.0 1,792.02011 Report on the Capacity, Demand, and Reserves in the ERCOT RegionWinter SummaryLoad Forecast:2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Total Winter Peak Demand, MW49,957 51,343 53,472 55,12656,39858,733 59,330 60,236 62,062 62,734less LAARs Serving as Responsive Reserve, MW 1,063 1,063 1,063 1,063 1,063 1,063 1,063 1,063 1,063 1,063less LAARs Serving as Non-Spinning Reserve, MW0000000000less Emergency Interruptible Load Service 421 463 509 560 616 678 745 820 902 992less Energy Efficiency Programs (per SB1125) 128 259 395 536 681 829 980 1133 1289 1448Firm Load Forecast, MW48,34549,55851,50552,96754,03856,16356,54157,22058,80859,231FirmLoadForecast,MWResources:2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Installed Capacity, MW66,531 66,531 66,531 66,531 66,531 66,531 66,531 66,531 66,531 66,531Capacity from Private Networks, MW5,103 5,134 5,134 5,134 5,134 5,134 5,134 5,134 5,134 5,134Effective Load-Carrying Capability (ELCC) of Wind Generation, MW822 822 822 822 822 822 822 822 822 822RMR Units to be under Contract, MW0000000000Operational Generation, MW72,456 72,487 72,487 72,487 72,487 72,487 72,487 72,487 72,487 72,48750% of Non-Synchronous Ties, MW553 553 553 553 553 553 553 553 553 553Switchable Units, MW3,168 3,168 3,168 3,168 3,168 3,168 3,168 3,168 3,168 3,168Available Mothballed Generation , MW110 110 100 100 100 100 100 100 100 100Planned Units (not wind) with Signed IA and Air Permit, MW825 1,940 1,940 2,720 5,500 6,120 6,780 6,780 6,780 6,780ELCC of Planned Wind Units with Signed IA, MW13 65 113 131 131 131 131 131 131 131Total Resources, MW77,125 78,323 78,361 79,159 81,939 82,559 83,219 83,219 83,219 83,219less Switchable Units Unavailable to ERCOT MW3173173173173173170000lessSwitchableUnitsUnavailabletoERCOT,MWless Retiring Units, MW0000000000Resources, MW 76,808 78,006 78,044 78,842 81,622 82,242 83,219 83,219 83,219 83,219Reserve Margin58.9% 57.4% 51.5% 48.9% 51.0% 46.4% 47.2% 45.4% 41.5% 40.5%(Resources - Firm Load Forecast)/Firm Load Forecast3,000 11,200 12,327 15,295 16,013 18,791 19,492 19,493 22,694 22,695Mothballed Capacity , MW2,447 2,447 2,457 2,457 2,457 2,457 2,457 2,457 2,457 2,45750% of Non-Synchronous Ties, MW 553 553 553 553 553 553 554 555 556 557Planned Units in Full Interconnection Study Phase, MW0 8,200 9,317 12,285 13,003 15,781 16,481 16,481 19,681 19,681Other Potential Resources:2011 Report on the Capacity, Demand, and Reserves in the ERCOT RegionWinter Loads and Resources85,00090,000MW54992.897 56372.218 58587.156 60250.185 61468.23 63885.412 64315.96 65087.34 66894 67375.4475,00080,00085,00060 00065,00070,00050 00055,00060,00040,00045,00050,00040,0002011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Firm Load ForecastResourcesForecast + Reserve MarginUnit NameUnit CodeCounty FuelForecastZone2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21A von Rosenberg 1-CT1BRAUNIG_AVR1_CT1 Bexar Gas South2000178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0A von Rosenberg 1-CT2BRAUNIG_AVR1_CT2 Bexar Gas South2000178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0A von Rosenberg 1-ST1BRAUNIG_AVR1_ST Bexar Gas South2000184.0 184.0 184.0 184.0 184.0 184.0 184.0 184.0 184.0 184.0AEDOMG 1DG_SUMMI_1UNITTravis Gas South20045.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0AES DeepwaterAPD_APD_PS1Harris Other Houston20101.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0Amistad Hydro 1AMISTAD_AMISTAG1 Val Verde Hydro South198337.9 37.9 37.9 37.9 37.9 37.9 37.9 37.9 37.9 37.9Amistad Hydro 2AMISTAD_AMISTAG2 Val Verde Hydro South198337.9 37.9 37.9 37.9 37.9 37.9 37.9 37.9 37.9 37.9Atascocita 1_HB_DG1Harris Biomass Houston200310.1 10.1 10.1 10.1 10.1 10.1 10.1 10.1 10.1 10.1Atkins 7ATKINS_ATKINSG7 Brazos Gas North197320.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0Austin 1AUSTPL_AUSTING1 Travis Hydro South19408.0 8.0 8.0 8.0 8.0 8.0 8.0 8.0 8.0 8.0Austin 2AUSTPL_AUSTING2 Travis Hydro South19409.0 9.0 9.0 9.0 9.0 9.0 9.0 9.0 9.0 9.0Austin Landfill GasDG_SPRIN_4UNITS Travis Other South19886.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4B M Davis 1B_DAVIS_B_DAVIG1 Nueces Gas South1974335.0 335.0 335.0 335.0 335.0 335.0 335.0 335.0 335.0 335.0B M Davis 2B_DAVIS_B_DAVIG2 Nueces Gas South1976332.0 332.0 332.0 332.0 332.0 332.0 332.0 332.0 332.0 332.0B M Davis 3B_DAVIS_B_DAVIG3 Nueces Gas South2009176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0B M Davis 4B_DAVIS_B_DAVIG4 Nueces Gas South2009176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0Bastrop Energy Center 1BASTEN_GTG1100 Bastrop Gas South2002167.0 167.0 167.0 167.0 167.0 167.0 167.0 167.0 167.0 167.0Bastrop Energy Center 2BASTEN_GTG2100 Bastrop Gas South2002167.0 167.0 167.0 167.0 167.0 167.0 167.0 167.0 167.0 167.0Bastrop Energy Center 3BASTEN_ST0100Bastrop Gas South2002234.0 234.0 234.0 234.0 234.0 234.0 234.0 234.0 234.0 234.0Baytown 1TRN_DG1Chambers Biomass Houston20033.9 3.9 3.9 3.9 3.9 3.9 3.9 3.9 3.9 3.9Big Brown 1BBSES_UNIT1Freestone Coal North1971606.0 606.0 606.0 606.0 606.0 606.0 606.0 606.0 606.0 606.0Big Brown 2BBSES_UNIT2Freestone Coal North1972602.0 602.0 602.0 602.0 602.0 602.0 602.0 602.0 602.0 602.0Bio Energy PartnersDG_BIOE_2UNITSDenton Gas North19885.6 5.6 5.6 5.6 5.6 5.6 5.6 5.6 5.6 5.6Bluebonnet 1_LB_DG1Harris Biomass Houston20033.9 3.9 3.9 3.9 3.9 3.9 3.9 3.9 3.9 3.9Bosque County Peaking 1BOSQUESW BSQSU 1BosqueGasNorth2000176 0176 0176 0176 0176 0176 0176 0176 0176 0176 0Units used in determining the generation resources in the Winter SummaryUnit Capacities - WinterOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. This list includes MW available to the grid from private network (self-serve) units. It also includes distributedgeneration units that have registered with ERCOT. Data without unit names are for private network units or are planned generation that is not public.BosqueCountyPeaking1BOSQUESW_BSQSU_1BosqueGasNorth2000176.0176.0176.0176.0176.0176.0176.0176.0176.0176.0Bosque County Peaking 2 BOSQUESW_BSQSU_2 Bosque Gas North2000175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0Bosque County Peaking 3 BOSQUESW_BSQSU_3 Bosque Gas North2001160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0Bosque County Peaking 4 BOSQUESW_BSQSU_4 Bosque Gas North200183.0 83.0 83.0 83.0 83.0 83.0 83.0 83.0 83.0 83.0Bosque County Unit 5BOSQUESW_BSQSU_5 Bosque Gas North2009245.0 245.0 245.0 245.0 245.0 245.0 245.0 245.0 245.0 245.0Brazos Valley 1BVE_UNIT1Ft Bend Gas Houston2003170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0Brazos Valley 2BVE_UNIT2Ft Bend Gas Houston2003170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0Brazos Valley 3BVE_UNIT3Ft Bend Gas Houston2003267.0 267.0 267.0 267.0 267.0 267.0 267.0 267.0 267.0 267.0Buchanan 1BUCHAN_BUCHANG1 Llano Hydro South193818.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0Buchanan 2BUCHAN_BUCHANG2 Llano Hydro South193818.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0Buchanan 3BUCHAN_BUCHANG3 Llano Hydro South195018.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0Calenergy (Falcon Seaboard) 1 FLCNS_UNIT1Howard Gas West198775.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0Calenergy (Falcon Seaboard) 2 FLCNS_UNIT2Howard Gas West198775.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0Calenergy (Falcon Seaboard) 3 FLCNS_UNIT3Howard Gas West198870.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0 70.0Canyon 1CANYHY_CANYHYG1 Comal Hydro South19893.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0Canyon 2CANYHY_CANYHYG2 Comal Hydro South19893.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0Cedar Bayou 1CBY_CBY_G1Chambers Gas Houston1970745.0 745.0 745.0 745.0 745.0 745.0 745.0 745.0 745.0 745.0Cedar Bayou 2CBY_CBY_G2Chambers Gas Houston1972749.0 749.0 749.0 749.0 749.0 749.0 749.0 749.0 749.0 749.0Cedar Bayou 4CBY4_CT41Chambers Gas Houston2009205.0 205.0 205.0 205.0 205.0 205.0 205.0 205.0 205.0 205.0Cedar Bayou 5CBY4_CT42Chambers Gas Houston2009205.0 205.0 205.0 205.0 205.0 205.0 205.0 205.0 205.0 205.0Cedar Bayou 6CBY4_ST04Chambers Gas Houston2009205.0 205.0 205.0 205.0 205.0 205.0 205.0 205.0 205.0 205.0Coastal Plains RDF_AV_DG1Galveston Biomass Houston20036.7 6.7 6.7 6.7 6.7 6.7 6.7 6.7 6.7 6.7Coleto CreekCOLETO_COLETOG1 Goliad Coal South1980640.0 640.0 640.0 640.0 640.0 640.0 640.0 640.0 640.0 640.0Unit NameUnit CodeCounty FuelForecastZone2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Units used in determining the generation resources in the Winter SummaryUnit Capacities - WinterOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. This list includes MW available to the grid from private network (self-serve) units. It also includes distributedgeneration units that have registered with ERCOT. Data without unit names are for private network units or are planned generation that is not public.Colorado Bend Energy Center CBEC_GT4Wharton Gas Houston200883.0 83.0 83.0 83.0 83.0 83.0 83.0 83.0 83.0 83.0Colorado Bend Energy Center CBEC_GT2Wharton Gas Houston200784.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0Colorado Bend Energy Center CBEC_GT1Wharton Gas Houston200788.0 88.0 88.0 88.0 88.0 88.0 88.0 88.0 88.0 88.0Colorado Bend Energy Center CBEC_GT3Wharton Gas Houston200888.0 88.0 88.0 88.0 88.0 88.0 88.0 88.0 88.0 88.0Colorado Bend Energy Center CBEC_STG1Wharton Gas Houston2007105.0 105.0 105.0 105.0 105.0 105.0 105.0 105.0 105.0 105.0Colorado Bend Energy Center CBEC_STG2Wharton Gas Houston2008108.0 108.0 108.0 108.0 108.0 108.0 108.0 108.0 108.0 108.0Comanche Peak 1CPSES_UNIT1Somervell Nuclear North19901230.0 1230.0 1230.0 1230.0 1230.0 1230.0 1230.0 1230.0 1230.0 1230.0Comanche Peak 2CPSES_UNIT2Somervell Nuclear North19931218.0 1218.0 1218.0 1218.0 1218.0 1218.0 1218.0 1218.0 1218.0 1218.0Covel Gardens LG Power Stn DG_MEDIN_1UNITBexar Other South200510.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0CVC Channelview 1CVC_CVC_G1Harris Gas Houston2008180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0CVC Channelview 2CVC_CVC_G2Harris Gas Houston2008175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0CVC Channelview 3CVC_CVC_G3Harris Gas Houston2008174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0CVC Channelview 5CVC_CVC_G5Harris Gas Houston2008118.0 118.0 118.0 118.0 118.0 118.0 118.0 118.0 118.0 118.0Dansby 1DANSBY_DANSBYG1 Brazos Gas North1978110.0 110.0 110.0 110.0 110.0 110.0 110.0 110.0 110.0 110.0Dansby 2DANSBY_DANSBYG2 Brazos Gas North200448.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Dansby 3DANSBY_DANSBYG3 Brazos Gas North201048.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Decker Creek 1DECKER_DPG1Travis Gas South2000320.0 320.0 320.0 320.0 320.0 320.0 320.0 320.0 320.0 320.0Decker Creek 2DECKER_DPG2Travis Gas South2000428.0 428.0 428.0 428.0 428.0 428.0 428.0 428.0 428.0 428.0Decker Creek G1DECKER_DPGT_1Travis Gas South200054.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0Decker Creek G2DECKER_DPGT_2Travis Gas South200054.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0Decker Creek G3DECKER_DPGT_3Travis Gas South200054.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0Decker Creek G4DECKER_DPGT_4Travis Gas South200054.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0DeCordova ADCSES_CT10Hood Gas North201080.0 80.0 80.0 80.0 80.0 80.0 80.0 80.0 80.0 80.0DeCordova BDCSES_CT20Hood Gas North201079.0 79.0 79.0 79.0 79.0 79.0 79.0 79.0 79.0 79.0DeCordova CDCSES CT30HoodGasNorth201078 078 078 078 078 078 078 078 078 078 0DeCordovaCDCSES_CT30..........DeCordova DDCSES_CT40Hood Gas North201077.0 77.0 77.0 77.0 77.0 77.0 77.0 77.0 77.0 77.0Deer Park Energy Center 1 DDPEC_GT1Harris Gas Houston2002185.5 185.5 185.5 185.5 185.5 185.5 185.5 185.5 185.5 185.5Deer Park Energy Center 2 DDPEC_GT2Harris Gas Houston2002182.9 182.9 182.9 182.9 182.9 182.9 182.9 182.9 182.9 182.9Deer Park Energy Center 3 DDPEC_GT3Harris Gas Houston2002173.6 173.6 173.6 173.6 173.6 173.6 173.6 173.6 173.6 173.6Deer Park Energy Center 4 DDPEC_GT4Harris Gas Houston2002186.6 186.6 186.6 186.6 186.6 186.6 186.6 186.6 186.6 186.6Deer Park Energy Center S DDPEC_ST1Harris Gas Houston2002290.2 290.2 290.2 290.2 290.2 290.2 290.2 290.2 290.2 290.2Denison Dam 1DNDAM_DENISOG1 Grayson Hydro North194440.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0Denison Dam 2DNDAM_DENISOG2 Grayson Hydro North194840.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0DFW Gas RecoveryDG_BIO2_4UNITSDenton Biomass North19806.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4Dunlop (Schumansville) 1DG_SCHUM_2UNITS Guadalupe Hydro South19273.6 3.6 3.6 3.6 3.6 3.6 3.6 3.6 3.6 3.6Eagle Pass 1EAGLE_HY_EAGLE_HY1 Maverick Hydro South19542.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0Eagle Pass 2EAGLE_HY_EAGLE_HY2 Maverick Hydro South19542.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0Eagle Pass 3EAGLE_HY_EAGLE_HY3 Maverick Hydro South19542.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0Ennis Power Station 1ETCCS_UNIT1EllisGas North2002127.0 127.0 127.0 127.0 127.0 127.0 127.0 127.0 127.0 127.0Ennis Power Station 2ETCCS_CT1EllisGas North2002231.0 231.0 231.0 231.0 231.0 231.0 231.0 231.0 231.0 231.0ExTex La Porte Pwr Stn (AirPro) 1 AZ_AZ_G1Harris Gas Houston200945.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0ExTex La Porte Pwr Stn (AirPro) 2 AZ_AZ_G2Harris Gas Houston200945.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0ExTex La Porte Pwr Stn (AirPro) 4 AZ_AZ_G4Harris Gas Houston200945.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0ExTex La Porte Pwr Stn(AirPro) 3 AZ_AZ_G3Harris Gas Houston200945.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0Falcon Hydro 1FALCON_FALCONG1 Starr Hydro South195412.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0Falcon Hydro 2FALCON_FALCONG2 Starr Hydro South195412.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0Falcon Hydro 3FALCON_FALCONG3 Starr Hydro South195412.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0Unit NameUnit CodeCounty FuelForecastZone2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Units used in determining the generation resources in the Winter SummaryUnit Capacities - WinterOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. This list includes MW available to the grid from private network (self-serve) units. It also includes distributedgeneration units that have registered with ERCOT. Data without unit names are for private network units or are planned generation that is not public.Fayette Power Project 1 FPPYD1_FPP_G1 Fayette Coal South1979612.0 612.0 612.0 612.0 612.0 612.0 612.0 612.0 612.0 612.0Fayette Power Project 2 FPPYD1_FPP_G2 Fayette Coal South1980612.0 612.0 612.0 612.0 612.0 612.0 612.0 612.0 612.0 612.0Fayette Power Project 3 FPPYD2_FPP_G3 Fayette Coal South1988450.0 450.0 450.0 450.0 450.0 450.0 450.0 450.0 450.0 450.0Forney Energy Center GT11 FRNYPP_GT11Kaufman Gas North2003188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2Forney Energy Center GT12 FRNYPP_GT12Kaufman Gas North2003188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2Forney Energy Center GT13 FRNYPP_GT13Kaufman Gas North2003188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2Forney Energy Center GT21 FRNYPP_GT21Kaufman Gas North2003188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2Forney Energy Center GT22 FRNYPP_GT22Kaufman Gas North2003188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2Forney Energy Center GT23 FRNYPP_GT23Kaufman Gas North2003188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2 188.2Forney Energy Center STG10 FRNYPP_ST10Kaufman Gas North2003405.0 405.0 405.0 405.0 405.0 405.0 405.0 405.0 405.0 405.0Forney Energy Center STG20 FRNYPP_ST20Kaufman Gas North2003405.0 405.0 405.0 405.0 405.0 405.0 405.0 405.0 405.0 405.0Freestone Energy Center 1 FREC_GT1Freestone Gas North2002170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0Freestone Energy Center 2 FREC_GT2Freestone Gas North2002170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0Freestone Energy Center 3 FREC_ST3Freestone Gas North2002180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0Freestone Energy Center 4 FREC_GT4Freestone Gas North2002170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0Freestone Energy Center 5 FREC_GT5Freestone Gas North2002170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0Freestone Energy Center 6 FREC_ST6Freestone Gas North2002180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0Fresno EnergyDG__SO_1UNITFort Bend Other Houston20101.6 1.6 1.6 1.6 1.6 1.6 1.6 1.6 1.6 1.6Frontera 1FRONTERA_FRONTEG1 Hidalgo Gas South1999159.0 159.0 159.0 159.0 159.0 159.0 159.0 159.0 159.0 159.0Frontera 2FRONTERA_FRONTEG2 Hidalgo Gas South1999159.0 159.0 159.0 159.0 159.0 159.0 159.0 159.0 159.0 159.0Frontera 3FRONTERA_FRONTEG3 Hidalgo Gas South2000184.0 184.0 184.0 184.0 184.0 184.0 184.0 184.0 184.0 184.0FW Region LFG Gen Facility 1 DG_RDLML_1UNITTarrant Other North19881.5 1.5 1.5 1.5 1.5 1.5 1.5 1.5 1.5 1.5GBRA 4 & 5DG_LKWDT_2UNITS Gonzales Other South19314.8 4.8 4.8 4.8 4.8 4.8 4.8 4.8 4.8 4.8Gibbons Creek 1GIBCRK_GIB_CRG1 Grimes Coal North1982470.0 470.0 470.0 470.0 470.0 470.0 470.0 470.0 470.0 470.0Graham 1GRSES UNIT1YoungGasWest1960225 0225 0225 0225 0225 0225 0225 0225 0225 0225 0Graham1GRSES_UNIT1..........Graham 2GRSES_UNIT2Young Gas West1969390.0 390.0 390.0 390.0 390.0 390.0 390.0 390.0 390.0 390.0Granite Shoals 1WIRTZ_WIRTZ_G1Burnet Hydro South195130.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0Granite Shoals 2WIRTZ_WIRTZ_G2Burnet Hydro South195130.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0Greens Bayou 5GBY_GBY_5Harris Gas Houston1973406.0 406.0 406.0 406.0 406.0 406.0 406.0 406.0 406.0 406.0Greens Bayou 73GBY_GBYGT73Harris Gas Houston197654.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0Greens Bayou 74GBY_GBYGT74Harris Gas Houston197654.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0Greens Bayou 81GBY_GBYGT81Harris Gas Houston197654.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0 54.0Greens Bayou 82GBY_GBYGT82Harris Gas Houston197658.0 58.0 58.0 58.0 58.0 58.0 58.0 58.0 58.0 58.0Greens Bayou 83GBY_GBYGT83Harris Gas Houston197664.0 64.0 64.0 64.0 64.0 64.0 64.0 64.0 64.0 64.0Greens Bayou 84GBY_GBYGT84Harris Gas Houston197658.0 58.0 58.0 58.0 58.0 58.0 58.0 58.0 58.0 58.0Greenville Engine PlantSTEAM_ENGINE_1 Hunt Gas North20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Greenville Engine PlantSTEAM_ENGINE_2 Hunt Gas North20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Greenville Engine PlantSTEAM_ENGINE_3 Hunt Gas North20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Guadalupe Gen Stn 1GUADG_GAS1Guadalupe Gas South2000169.0 169.0 169.0 169.0 169.0 169.0 169.0 169.0 169.0 169.0Guadalupe Gen Stn 2GUADG_GAS2Guadalupe Gas South2000169.0 169.0 169.0 169.0 169.0 169.0 169.0 169.0 169.0 169.0Guadalupe Gen Stn 3GUADG_GAS3Guadalupe Gas South2000167.0 167.0 167.0 167.0 167.0 167.0 167.0 167.0 167.0 167.0Guadalupe Gen Stn 4GUADG_GAS4Guadalupe Gas South2000170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0Guadalupe Gen Stn 5GUADG_STM5Guadalupe Gas South2000178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0Guadalupe Gen Stn 6GUADG_STM6Guadalupe Gas South2000171.0 171.0 171.0 171.0 171.0 171.0 171.0 171.0 171.0 171.0Handley 3HLSES_UNIT3Tarrant Gas North1963395.0 395.0 395.0 395.0 395.0 395.0 395.0 395.0 395.0 395.0Handley 4HLSES_UNIT4Tarrant Gas North1976435.0 435.0 435.0 435.0 435.0 435.0 435.0 435.0 435.0 435.0Handley 5HLSES_UNIT5Tarrant Gas North1977435.0 435.0 435.0 435.0 435.0 435.0 435.0 435.0 435.0 435.0Unit NameUnit CodeCounty FuelForecastZone2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Units used in determining the generation resources in the Winter SummaryUnit Capacities - WinterOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. This list includes MW available to the grid from private network (self-serve) units. It also includes distributedgeneration units that have registered with ERCOT. Data without unit names are for private network units or are planned generation that is not public.Hays Energy Facility 1HAYSEN_HAYSENG1 Hays Gas South2002237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0Hays Energy Facility 2HAYSEN_HAYSENG2 Hays Gas South2002237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0Hays Energy Facility 3HAYSEN_HAYSENG3 Hays Gas South2002247.0 247.0 247.0 247.0 247.0 247.0 247.0 247.0 247.0 247.0Hays Energy Facility 4HAYSEN_HAYSENG4 Hays Gas South2002247.0 247.0 247.0 247.0 247.0 247.0 247.0 247.0 247.0 247.0Hidalgo 1DUKE_DUKE_GT1Hidalgo Gas South2000162.0 162.0 162.0 162.0 162.0 162.0 162.0 162.0 162.0 162.0Hidalgo 2DUKE_DUKE_GT2Hidalgo Gas South2000162.0 162.0 162.0 162.0 162.0 162.0 162.0 162.0 162.0 162.0Hidalgo 3DUKE_DUKE_ST1Hidalgo Gas South2000170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0Inks 1INKSDA_INKS_G1Llano Hydro South193814.0 14.0 14.0 14.0 14.0 14.0 14.0 14.0 14.0 14.0J K Spruce 1CALAVERS_JKS1Bexar Coal South1992565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0J K Spruce 2CALAVERS_JKS2Bexar Coal South2010785.0 785.0 785.0 785.0 785.0 785.0 785.0 785.0 785.0 785.0J T Deely 1CALAVERS_JTD1Bexar Coal South1977445.0 445.0 445.0 445.0 445.0 445.0 445.0 445.0 445.0 445.0J T Deely 2CALAVERS_JTD2Bexar Coal South1978445.0 445.0 445.0 445.0 445.0 445.0 445.0 445.0 445.0 445.0Jack County GenFacility 1 JACKCNTY_CT1Jack Gas North2005165.0 165.0 165.0 165.0 165.0 165.0 165.0 165.0 165.0 165.0Jack County GenFacility 1 JACKCNTY_CT2Jack Gas North2005165.0 165.0 165.0 165.0 165.0 165.0 165.0 165.0 165.0 165.0Jack County GenFacility 1 JACKCNTY_STGJack Gas North2005310.0 310.0 310.0 310.0 310.0 310.0 310.0 310.0 310.0 310.0Johnson County GenFacility 1 TEN_CT1Johnson Gas North1997177.0 177.0 177.0 177.0 177.0 177.0 177.0 177.0 177.0 177.0Johnson County GenFacility 2 TEN_STGJohnson Gas North1997106.0 106.0 106.0 106.0 106.0 106.0 106.0 106.0 106.0 106.0Lake Hubbard 1LHSES_UNIT1Dallas Gas North1970392.0 392.0 392.0 392.0 392.0 392.0 392.0 392.0 392.0 392.0Lake Hubbard 2LH2SES_UNIT2Dallas Gas North2010524.0 524.0 524.0 524.0 524.0 524.0 524.0 524.0 524.0 524.0Lamar Power Project CT11 LPCCS_CT11Lamar Gas North2000176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0Lamar Power Project CT12 LPCCS_CT12Lamar Gas North2000176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0Lamar Power Project CT21 LPCCS_CT21Lamar Gas North2000176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0Lamar Power Project CT22 LPCCS_CT22Lamar Gas North2000176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0 176.0Lamar Power Project STG1 LPCCS_UNIT1Lamar Gas North2000204.3 204.3 204.3 204.3 204.3 204.3 204.3 204.3 204.3 204.3Lamar Power Project STG2LPCCS UNIT2LamarGasNorth2000204 3204 3204 3204 3204 3204 3204 3204 3204 3204 3LamarPowerProjectSTG2LPCCS_UNIT2..........Laredo Peaking 4LARDVFTN_G4Webb Gas South200898.5 98.5 98.5 98.5 98.5 98.5 98.5 98.5 98.5 98.5Laredo Peaking 5LARDVFTN_G5Webb Gas South200898.5 98.5 98.5 98.5 98.5 98.5 98.5 98.5 98.5 98.5Leon Creek Peaking 1LEON_CRK_LCPCT1 Bexar Gas South200448.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Leon Creek Peaking 2LEON_CRK_LCPCT2 Bexar Gas South200448.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Leon Creek Peaking 3LEON_CRK_LCPCT3 Bexar Gas South200448.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Leon Creek Peaking 4LEON_CRK_LCPCT4 Bexar Gas South200448.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Lewisville 1DG_LWSVL_1UNIT Denton Hydro North19922.8 2.8 2.8 2.8 2.8 2.8 2.8 2.8 2.8 2.8Limestone 1LEG_LEG_G1Limestone Coal North1985831.0 831.0 831.0 831.0 831.0 831.0 831.0 831.0 831.0 831.0Limestone 2LEG_LEG_G2Limestone Coal North1986858.0 858.0 858.0 858.0 858.0 858.0 858.0 858.0 858.0 858.0Lost Pines 1LOSTPI_LOSTPGT1 Bastrop Gas South2001183.0 183.0 183.0 183.0 183.0 183.0 183.0 183.0 183.0 183.0Lost Pines 2LOSTPI_LOSTPGT2 Bastrop Gas South2001178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0Lost Pines 3LOSTPI_LOSTPST1 Bastrop Gas South2001193.0 193.0 193.0 193.0 193.0 193.0 193.0 193.0 193.0 193.0Lufkin BiomassLFBIO_UNIT1Angelina Biomass North201148.2 48.2 48.2 48.2 48.2 48.2 48.2 48.2 48.2 48.2Magic Valley 1NEDIN_NEDIN_G1Hidalgo Gas South2001250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0Magic Valley 2NEDIN_NEDIN_G2Hidalgo Gas South2001250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0Magic Valley 3NEDIN_NEDIN_G3Hidalgo Gas South2001250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0Marble Falls 1MARBFA_MARBFAG1 Burnet Hydro South195121.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0Marble Falls 2MARBFA_MARBFAG2 Burnet Hydro South195121.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0Marshall Ford 1MARSFO_MARSFOG1 Travis Hydro South194136.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0Marshall Ford 2MARSFO_MARSFOG2 Travis Hydro South194136.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0Marshall Ford 3MARSFO_MARSFOG3 Travis Hydro South194129.0 29.0 29.0 29.0 29.0 29.0 29.0 29.0 29.0 29.0Martin Lake 1MLSES_UNIT1Rusk Coal North1977815.0 815.0 815.0 815.0 815.0 815.0 815.0 815.0 815.0 815.0Unit NameUnit CodeCounty FuelForecastZone2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Units used in determining the generation resources in the Winter SummaryUnit Capacities - WinterOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. This list includes MW available to the grid from private network (self-serve) units. It also includes distributedgeneration units that have registered with ERCOT. Data without unit names are for private network units or are planned generation that is not public.Martin Lake 2 MLSES_UNIT2 Rusk Coal North1978820.0 820.0 820.0 820.0 820.0 820.0 820.0 820.0 820.0 820.0Martin Lake 3 MLSES_UNIT3 Rusk Coal North1979820.0 820.0 820.0 820.0 820.0 820.0 820.0 820.0 820.0 820.0McQueeney (Abbott) DG_MCQUE_5UNITS Guadalupe Hydro South19278.0 8.0 8.0 8.0 8.0 8.0 8.0 8.0 8.0 8.0Midlothian 1 MDANP_CT1 Ellis Gas North2001237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0Midlothian 2 MDANP_CT2 Ellis Gas North2001237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0Midlothian 3 MDANP_CT3 Ellis Gas North2001237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0Midlothian 4 MDANP_CT4 Ellis Gas North2001237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0 237.0Midlothian 5 MDANP_CT5 Ellis Gas North2002247.0 247.0 247.0 247.0 247.0 247.0 247.0 247.0 247.0 247.0Midlothian 6 MDANP_CT6 Ellis Gas North2002247.0 247.0 247.0 247.0 247.0 247.0 247.0 247.0 247.0 247.0Monticello 1 MNSES_UNIT1 Titus Coal North1974580.0 580.0 580.0 580.0 580.0 580.0 580.0 580.0 580.0 580.0Monticello 2 MNSES_UNIT2 Titus Coal North1975580.0 580.0 580.0 580.0 580.0 580.0 580.0 580.0 580.0 580.0Monticello 3 MNSES_UNIT3 Titus Coal North1978790.0 790.0 790.0 790.0 790.0 790.0 790.0 790.0 790.0 790.0Morgan Creek AMGSES_CT1Mitchell Gas West198881.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0Morgan Creek BMGSES_CT2Mitchell Gas West198881.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0Morgan Creek CMGSES_CT3Mitchell Gas West198881.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0Morgan Creek DMGSES_CT4Mitchell Gas West198881.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0Morgan Creek EMGSES_CT5Mitchell Gas West198881.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0Morgan Creek FMGSES_CT6Mitchell Gas West198881.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0Mountain Creek 6MCSES_UNIT6Dallas Gas North1956122.0 122.0 122.0 122.0 122.0 122.0 122.0 122.0 122.0 122.0Mountain Creek 7MCSES_UNIT7Dallas Gas North1958118.0 118.0 118.0 118.0 118.0 118.0 118.0 118.0 118.0 118.0Mountain Creek 8MCSES_UNIT8Dallas Gas North1967568.0 568.0 568.0 568.0 568.0 568.0 568.0 568.0 568.0 568.0Nelson Gardens Landfill 1DG_PEARS_2UNITS Bexar Other South19903.6 3.6 3.6 3.6 3.6 3.6 3.6 3.6 3.6 3.6Nueces Bay 7NUECES_B_NUECESG7 Nueces Gas South1972348.0 348.0 348.0 348.0 348.0 348.0 348.0 348.0 348.0 348.0Nueces Bay 8NUECES_B_NUECESG8 Nueces Gas South2009190.1 190.1 190.1 190.1 190.1 190.1 190.1 190.1 190.1 190.1Nueces Bay 9NUECES B NUECESG9NuecesGasSouth2009190 1190 1190 1190 1190 1190 1190 1190 1190 1190 1NuecesBay9NUECES_B_NUECESG9..........O W Sommers 1CALAVERS_OWS1Bexar Gas South1972420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0O W Sommers 2CALAVERS_OWS2Bexar Gas South1974420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0Oak Grove SES Unit 1OGSES_UNIT1ARobertson Coal North2011820.0 820.0 820.0 820.0 820.0 820.0 820.0 820.0 820.0 820.0Oak Grove SES Unit 2OGSES_UNIT2Robertson Coal North2011796.0 796.0 796.0 796.0 796.0 796.0 796.0 796.0 796.0 796.0Oak Ridge North 1-3DG__RA_3UNITSMontgomery Other Houston19934.8 4.8 4.8 4.8 4.8 4.8 4.8 4.8 4.8 4.8Odessa-Ector Gen Stn C11 OECCS_CT11Ector Gas West2001160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0 160.0Odessa-Ector Gen Stn C12 OECCS_CT12Ector Gas West2001155.0 155.0 155.0 155.0 155.0 155.0 155.0 155.0 155.0 155.0Odessa-Ector Gen Stn C21 OECCS_CT21Ector Gas West2001151.0 151.0 151.0 151.0 151.0 151.0 151.0 151.0 151.0 151.0Odessa-Ector Gen Stn C22 OECCS_CT22Ector Gas West2001168.0 168.0 168.0 168.0 168.0 168.0 168.0 168.0 168.0 168.0Odessa-Ector Gen Stn ST1 OECCS_UNIT1Ector Gas West2001216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0Odessa-Ector Gen Stn ST2 OECCS_UNIT2Ector Gas West2001216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0 216.0Oklaunion 1OKLA_OKLA_G1Wilbarger Coal West1986650.0 650.0 650.0 650.0 650.0 650.0 650.0 650.0 650.0 650.0Paris Energy Center 1TNSKA_GT1Lamar Gas North198987.0 87.0 87.0 87.0 87.0 87.0 87.0 87.0 87.0 87.0Paris Energy Center 2TNSKA_GT2Lamar Gas North198987.0 87.0 87.0 87.0 87.0 87.0 87.0 87.0 87.0 87.0Paris Energy Center 3TNSKA_STGLamar Gas North199089.0 89.0 89.0 89.0 89.0 89.0 89.0 89.0 89.0 89.0PasGenPSG_PSG_ST2Harris Gas Houston2000177.0 177.0 177.0 177.0 177.0 177.0 177.0 177.0 177.0 177.0PasGenPSG_PSG_GT2Harris Gas Houston2000185.0 185.0 185.0 185.0 185.0 185.0 185.0 185.0 185.0 185.0PasGenPSG_PSG_GT3Harris Gas Houston2000185.0 185.0 185.0 185.0 185.0 185.0 185.0 185.0 185.0 185.0Pearsall 1PEARSALL_PEARS_1 FrioGas South196125.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0Pearsall 2PEARSALL_PEARS_2 FrioGas South196125.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0Pearsall 3PEARSALL_PEARS_3 FrioGas South196125.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0Pearsall Engine PlantPEARSAL2_ENG1FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Unit NameUnit CodeCounty FuelForecastZone2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Units used in determining the generation resources in the Winter SummaryUnit Capacities - WinterOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. This list includes MW available to the grid from private network (self-serve) units. It also includes distributedgeneration units that have registered with ERCOT. Data without unit names are for private network units or are planned generation that is not public.Pearsall Engine PlantPEARSAL2_ENG10 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG11 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG12 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG13 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG14 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG15 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG16 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG17 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG18 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG19 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG2FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG20 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG21 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG22 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG23 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG24 FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG3FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG4FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG5FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG6FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG7FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG8FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Pearsall Engine PlantPEARSAL2_ENG9FrioGas South20108.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4 8.4Permian Basin APB2SES_CT1Ward Gas West198871.0 71.0 71.0 71.0 71.0 71.0 71.0 71.0 71.0 71.0Permian Basin BPB2SES CT2WardGasWest198871 071 071 071 071 071 071 071 071 071 0PermianBasinBPB2SES_CT2..........Permian Basin CPB2SES_CT3Ward Gas West198874.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0Permian Basin DPB2SES_CT4Ward Gas West199075.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0Permian Basin EPB2SES_CT5Ward Gas West199075.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0Powerlane Plant 1STEAM1A_STEAM_1 Hunt Gas North200920.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0 20.0Powerlane Plant 2STEAM_STEAM_2Hunt Gas North196726.0 26.0 26.0 26.0 26.0 26.0 26.0 26.0 26.0 26.0Powerlane Plant 3STEAM_STEAM_3Hunt Gas North197841.0 41.0 41.0 41.0 41.0 41.0 41.0 41.0 41.0 41.0Quail Run Energy GT1QALSW_GT2Ector Gas West200786.0 86.0 86.0 86.0 86.0 86.0 86.0 86.0 86.0 86.0Quail Run Energy GT2QALSW_GT3Ector Gas West200881.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0Quail Run Energy GT3QALSW_STG1Ector Gas West2007102.0 102.0 102.0 102.0 102.0 102.0 102.0 102.0 102.0 102.0Quail Run Energy GT4QALSW_STG2Ector Gas West2008106.0 106.0 106.0 106.0 106.0 106.0 106.0 106.0 106.0 106.0Quail Run Energy STG1QALSW_GT1Ector Gas West200784.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0Quail Run Energy STG2QALSW_GT4Ector Gas West200881.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0R W Miller 1MIL_MILLERG1Palo Pinto Gas North200075.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0 75.0R W Miller 2MIL_MILLERG2Palo Pinto Gas North2000120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0R W Miller 3MIL_MILLERG3Palo Pinto Gas North2000208.0 208.0 208.0 208.0 208.0 208.0 208.0 208.0 208.0 208.0R W Miller 4MIL_MILLERG4Palo Pinto Gas North2000115.0 115.0 115.0 115.0 115.0 115.0 115.0 115.0 115.0 115.0R W Miller 5MIL_MILLERG5Palo Pinto Gas North2000115.0 115.0 115.0 115.0 115.0 115.0 115.0 115.0 115.0 115.0Ray Olinger 1OLINGR_OLING_1Collin Gas North196778.0 78.0 78.0 78.0 78.0 78.0 78.0 78.0 78.0 78.0Ray Olinger 2OLINGR_OLING_2Collin Gas North1971107.0 107.0 107.0 107.0 107.0 107.0 107.0 107.0 107.0 107.0Ray Olinger 3OLINGR_OLING_3Collin Gas North1975146.0 146.0 146.0 146.0 146.0 146.0 146.0 146.0 146.0 146.0Ray Olinger 4OLINGR_OLING_4Collin Gas North200184.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0Rayburn 1RAYBURN_RAYBURG1 Victoria Gas South196313.5 13.5 13.5 13.5 13.5 13.5 13.5 13.5 13.5 13.5Unit NameUnit CodeCounty FuelForecastZone2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Units used in determining the generation resources in the Winter SummaryUnit Capacities - WinterOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. This list includes MW available to the grid from private network (self-serve) units. It also includes distributedgeneration units that have registered with ERCOT. Data without unit names are for private network units or are planned generation that is not public.Rayburn 10RAYBURN_RAYBURG10 Victoria Gas South200340.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0 40.0Rayburn 2RAYBURN_RAYBURG2 Victoria Gas South196313.5 13.5 13.5 13.5 13.5 13.5 13.5 13.5 13.5 13.5Rayburn 3RAYBURN_RAYBURG3 Victoria Gas South196526.0 26.0 26.0 26.0 26.0 26.0 26.0 26.0 26.0 26.0Rayburn 7RAYBURN_RAYBURG7 Victoria Gas South200350.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0Rayburn 8RAYBURN_RAYBURG8 Victoria Gas South200351.0 51.0 51.0 51.0 51.0 51.0 51.0 51.0 51.0 51.0Rayburn 9RAYBURN_RAYBURG9 Victoria Gas South200350.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0RGV Sugar MillDG_S_SNR_UNIT1Hidalgo Biomass South19734.5 4.5 4.5 4.5 4.5 4.5 4.5 4.5 4.5 4.5Rhodia Houston PlantDG__HG_2UNITSHarris Other Houston19707.5 7.5 7.5 7.5 7.5 7.5 7.5 7.5 7.5 7.5Rio Nogales 1RIONOG_CT1Guadalupe Gas South2002175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0Rio Nogales 2RIONOG_CT2Guadalupe Gas South2002175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0Rio Nogales 3RIONOG_CT3Guadalupe Gas South2002175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0Rio Nogales 4RIONOG_ST1Guadalupe Gas South2002323.0 323.0 323.0 323.0 323.0 323.0 323.0 323.0 323.0 323.0Sam Bertron 3SRB_SRB_G3Harris Gas Houston1959230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0Sam Bertron 4SRB_SRB_G4Harris Gas Houston1960230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0Sam Bertron T2SRB_SRBGT_2Harris Gas Houston196713.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0San Jacinto SES 1SJS_SJS_G1Harris Gas Houston199581.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0San Jacinto SES 2SJS_SJS_G2Harris Gas Houston199581.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0 81.0San Miguel 1SANMIGL_SANMIGG1 Atascosa Coal South1982395.0 395.0 395.0 395.0 395.0 395.0 395.0 395.0 395.0 395.0Sandhill Energy Center 1SANDHSYD_SH1Travis Gas South200148.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Sandhill Energy Center 2SANDHSYD_SH2Travis Gas South200148.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Sandhill Energy Center 3SANDHSYD_SH3Travis Gas South200148.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Sandhill Energy Center 4SANDHSYD_SH4Travis Gas South200148.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Sandhill Energy Center 5A SANDHSYD_SH_5A Travis Gas South2004170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0 170.0Sandhill Energy Center 5C SANDHSYD_SH_5C Travis Gas South2004155.0 155.0 155.0 155.0 155.0 155.0 155.0 155.0 155.0 155.0Sandhill Energy Center 6SANDHSYD SH6TravisGasSouth201048 048 048 048 048 048 048 048 048 048 0SandhillEnergyCenter6SANDHSYD_SH6..........Sandhill Energy Center 7SANDHSYD_SH7Travis Gas South201048.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Sandow 5SD5SES_UNIT5Milam Coal South2010570.0 570.0 570.0 570.0 570.0 570.0 570.0 570.0 570.0 570.0Silas Ray 10SILASRAY_SILAS_10 Cameron Gas South200448.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Silas Ray 5SILASRAY_SILAS_5 Cameron Gas South195110.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0Silas Ray 6SILASRAY_SILAS_6 Cameron Gas South196121.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0Silas Ray 9SILASRAY_SILAS_9 Cameron Gas South199649.0 49.0 49.0 49.0 49.0 49.0 49.0 49.0 49.0 49.0Sim Gideon 1GIDEON_GIDEONG1 Bastrop Gas South1965140.0 140.0 140.0 140.0 140.0 140.0 140.0 140.0 140.0 140.0Sim Gideon 2GIDEON_GIDEONG2 Bastrop Gas South1968140.0 140.0 140.0 140.0 140.0 140.0 140.0 140.0 140.0 140.0Sim Gideon 3GIDEON_GIDEONG3 Bastrop Gas South1972340.0 340.0 340.0 340.0 340.0 340.0 340.0 340.0 340.0 340.0Skyline Landfill GasDG_FERIS_4UNITS Dallas Other North20076.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4 6.4Small Hydro of Texas 1CUECPL_UNIT1Dewitt Hydro South19921.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0South Texas 1STP_STP_G1Matagorda Nuclear South19881375.0 1375.0 1375.0 1375.0 1375.0 1375.0 1375.0 1375.0 1375.0 1375.0South Texas 2STP_STP_G2Matagorda Nuclear South19891375.0 1375.0 1375.0 1375.0 1375.0 1375.0 1375.0 1375.0 1375.0 1375.0Stryker Creek 1SCSES_UNIT1ACherokee Gas North1958171.0 171.0 171.0 171.0 171.0 171.0 171.0 171.0 171.0 171.0Stryker Creek 2SCSES_UNIT2Cherokee Gas North1965502.0 502.0 502.0 502.0 502.0 502.0 502.0 502.0 502.0 502.0T H Wharton 3THW_THWST_3Harris Gas Houston1974104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0T H Wharton 31THW_THWGT31Harris Gas Houston197257.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 32THW_THWGT32Harris Gas Houston197257.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 33THW_THWGT33Harris Gas Houston197257.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 34THW_THWGT34Harris Gas Houston197257.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 4THW_THWST_4Harris Gas Houston1974104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0 104.0T H Wharton 41THW_THWGT41Harris Gas Houston197257.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0Unit NameUnit CodeCounty FuelForecastZone2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Units used in determining the generation resources in the Winter SummaryUnit Capacities - WinterOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. This list includes MW available to the grid from private network (self-serve) units. It also includes distributedgeneration units that have registered with ERCOT. Data without unit names are for private network units or are planned generation that is not public.T H Wharton 42THW_THWGT42Harris Gas Houston197257.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 43THW_THWGT43Harris Gas Houston197457.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 44THW_THWGT44Harris Gas Houston197457.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 51THW_THWGT51Harris Gas Houston197557.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 52THW_THWGT52Harris Gas Houston197557.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 53THW_THWGT53Harris Gas Houston197557.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 54THW_THWGT54Harris Gas Houston197557.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 55THW_THWGT55Harris Gas Houston197557.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton 56THW_THWGT56Harris Gas Houston197557.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0 57.0T H Wharton G1THW_THWGT_1Harris Gas Houston196713.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0Tessman Road 1DG_WALZE_4UNITS Bexar Biomass South200310.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0Texas City 1TXCTY_CTAGalveston Gas Houston2000112.0 112.0 112.0 112.0 112.0 112.0 112.0 112.0 112.0 112.0Texas City 2TXCTY_CTBGalveston Gas Houston2000106.0 106.0 106.0 106.0 106.0 106.0 106.0 106.0 106.0 106.0Texas City 3TXCTY_CTCGalveston Gas Houston2000106.0 106.0 106.0 106.0 106.0 106.0 106.0 106.0 106.0 106.0Texas City 4TXCTY_STGalveston Gas Houston2000128.0 128.0 128.0 128.0 128.0 128.0 128.0 128.0 128.0 128.0Texas Gulf SulphurTGF_TGFGT_1Wharton Gas Houston198578.0 78.0 78.0 78.0 78.0 78.0 78.0 78.0 78.0 78.0Thomas C Ferguson 1FERGUS_FERGUSG1 Llano Gas South1974425.0 425.0 425.0 425.0 425.0 425.0 425.0 425.0 425.0 425.0Trinidad 6TRSES_UNIT6Henderson Gas North1965226.0 226.0 226.0 226.0 226.0 226.0 226.0 226.0 226.0 226.0Trinity Oaks LFGDG_KLBRG_1UNITDallas Biomass North20093.2 3.2 3.2 3.2 3.2 3.2 3.2 3.2 3.2 3.2Twin Oaks 1TNP_ONE_TNP_O_1 Robertson Coal North1990158.0 158.0 158.0 158.0 158.0 158.0 158.0 158.0 158.0 158.0Twin Oaks 2TNP_ONE_TNP_O_2 Robertson Coal North1991158.0 158.0 158.0 158.0 158.0 158.0 158.0 158.0 158.0 158.0V H Braunig 1BRAUNIG_VHB1Bexar Gas South1966220.0 220.0 220.0 220.0 220.0 220.0 220.0 220.0 220.0 220.0V H Braunig 2BRAUNIG_VHB2Bexar Gas South1968230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0 230.0V H Braunig 3BRAUNIG_VHB3Bexar Gas South1970412.0 412.0 412.0 412.0 412.0 412.0 412.0 412.0 412.0 412.0V H Braunig 5BRAUNIG VHB6CT5BexarGasSouth200948 048 048 048 048 048 048 048 048 048 0VHBraunig5BRAUNIG_VHB6CT5..........V H Braunig 6BRAUNIG_VHB6CT6 Bexar Gas South200948.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0V H Braunig 7BRAUNIG_VHB6CT7 Bexar Gas South200948.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0V H Braunig 8BRAUNIG_VHB6CT8 Bexar Gas South200948.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0 48.0Victoria Power Station 5VICTORIA_VICTORG5 Victoria Gas South2009132.0 132.0 132.0 132.0 132.0 132.0 132.0 132.0 132.0 132.0Victoria Power Station 6VICTORIA_VICTORG6 Victoria Gas South2009168.0 168.0 168.0 168.0 168.0 168.0 168.0 168.0 168.0 168.0W A Parish 1WAP_WAP_G1Ft. Bend Gas Houston1958169.0 169.0 169.0 169.0 169.0 169.0 169.0 169.0 169.0 169.0W A Parish 2WAP_WAP_G2Ft. Bend Gas Houston1958169.0 169.0 169.0 169.0 169.0 169.0 169.0 169.0 169.0 169.0W A Parish 3WAP_WAP_G3Ft. Bend Gas Houston1961273.0 273.0 273.0 273.0 273.0 273.0 273.0 273.0 273.0 273.0W A Parish 4WAP_WAP_G4Ft. Bend Gas Houston1968552.0 552.0 552.0 552.0 552.0 552.0 552.0 552.0 552.0 552.0W A Parish 5WAP_WAP_G5Ft. Bend Coal Houston1977648.0 648.0 648.0 648.0 648.0 648.0 648.0 648.0 648.0 648.0W A Parish 6WAP_WAP_G6Ft. Bend Coal Houston1978653.0 653.0 653.0 653.0 653.0 653.0 653.0 653.0 653.0 653.0W A Parish 7WAP_WAP_G7Ft. Bend Coal Houston1980577.0 577.0 577.0 577.0 577.0 577.0 577.0 577.0 577.0 577.0W A Parish 8WAP_WAP_G8Ft. Bend Coal Houston1982610.0 610.0 610.0 610.0 610.0 610.0 610.0 610.0 610.0 610.0W A Parish T1WAP_WAPGT_1Ft. Bend Gas Houston196713.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0Whitney 1WND_WHITNEY1Bosque Hydro North195315.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0Whitney 2WND_WHITNEY2Bosque Hydro North195315.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0Wichita Falls 1WFCOGEN_UNIT1Wichita Gas West198721.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0Wichita Falls 2WFCOGEN_UNIT2Wichita Gas West198721.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0Wichita Falls 3WFCOGEN_UNIT3Wichita Gas West198721.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0 21.0Wichita Falls 4WFCOGEN_UNIT4Wichita Gas West198716.0 16.0 16.0 16.0 16.0 16.0 16.0 16.0 16.0 16.0Winchester Power Park 1WIPOPA_WPP_G1Fayette Gas South201044.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8Winchester Power Park 2WIPOPA_WPP_G2Fayette Gas South201044.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8Unit NameUnit CodeCounty FuelForecastZone2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Units used in determining the generation resources in the Winter SummaryUnit Capacities - WinterOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. This list includes MW available to the grid from private network (self-serve) units. It also includes distributedgeneration units that have registered with ERCOT. Data without unit names are for private network units or are planned generation that is not public.Winchester Power Park 3WIPOPA_WPP_G3Fayette Gas South201044.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8Winchester Power Park 4WIPOPA_WPP_G4Fayette Gas South201044.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8 44.8Wise-Tractebel Power Proj. 1 WCPP_CT1Wise Gas North2004260.0 260.0 260.0 260.0 260.0 260.0 260.0 260.0 260.0 260.0Wise-Tractebel Power Proj. 2 WCPP_CT2Wise Gas North2004260.0 260.0 260.0 260.0 260.0 260.0 260.0 260.0 260.0 260.0Wise-Tractebel Power Proj. 3 WCPP_ST1Wise Gas North2004290.0 290.0 290.0 290.0 290.0 290.0 290.0 290.0 290.0 290.0Wolf Hollow Power Proj. 1 WHCCS_CT1Hood Gas North2002249.0 249.0 249.0 249.0 249.0 249.0 249.0 249.0 249.0 249.0Wolf Hollow Power Proj. 2 WHCCS_CT2Hood Gas North2002249.0 249.0 249.0 249.0 249.0 249.0 249.0 249.0 249.0 249.0Wolf Hollow Power Proj. 3 WHCCS_STGHood Gas North2002293.0 293.0 293.0 293.0 293.0 293.0 293.0 293.0 293.0 293.0Operational66,531 66,531 66,531 66,531 66,531 66,531 66,531 66,531 66,531 66,531Gas Houston660.0 660.0 660.0 660.0 660.0 660.0 660.0 660.0 660.0 660.0Gas Houston86.0 86.0 86.0 86.0 86.0 86.0 86.0 86.0 86.0 86.0Gas Houston185.0 185.0 185.0 185.0 185.0 185.0 185.0 185.0 185.0 185.0Gas Houston340.0 340.0 340.0 340.0 340.0 340.0 340.0 340.0 340.0 340.0Gas Houston190.0 190.0 190.0 190.0 190.0 190.0 190.0 190.0 190.0 190.0Gas West17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5Gas South381.0 381.0 381.0 381.0 381.0 381.0 381.0 381.0 381.0 381.0Gas South10.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0 13.0Gas Houston287.0 287.0 287.0 287.0 287.0 287.0 287.0 287.0 287.0 287.0Gas Houston310.0 310.0 310.0 310.0 310.0 310.0 310.0 310.0 310.0 310.0Gas Houston225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0 225.0Gas Houston0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Gas South0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Gas Houston145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0 145.0GasSouth70 0100 0100 0100 0100 0100 0100 0100 0100 0100 0..........Gas Houston1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0 1.0Gas South420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0 420.0Gas South0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Gas Houston120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0Gas South28.0 28.0 28.0 28.0 28.0 28.0 28.0 28.0 28.0 28.0Gas South43.2 43.2 43.2 43.2 43.2 43.2 43.2 43.2 43.2 43.2Gas Houston12.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0Gas Houston565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0 565.0Gas Houston325.0 325.0 325.0 325.0 325.0 325.0 325.0 325.0 325.0 325.0Coal South575.0 575.0 575.0 575.0 575.0 575.0 575.0 575.0 575.0 575.0Gas South3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0Gas Houston74.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0 74.0Gas Houston15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0Gas South15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0Generation from Private Use Networks5,102.7 5,133.7 5,133.7 5,133.7 5,133.7 5,133.7 5,133.7 5,133.7 5,133.7 5,133.7RMR0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Eagle PassDC TieMaverick Other South36.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0 36.0EastDC TieFannin Other North600.0 600.0 600.0 600.0 600.0 600.0 600.0 600.0 600.0 600.0Laredo VFTDC TieWebb Other South100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0NorthDC TieWilbarger Other West220.0 220.0 220.0 220.0 220.0 220.0 220.0 220.0 220.0 220.0Unit NameUnit CodeCounty FuelForecastZone2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Units used in determining the generation resources in the Winter SummaryUnit Capacities - WinterOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. This list includes MW available to the grid from private network (self-serve) units. It also includes distributedgeneration units that have registered with ERCOT. Data without unit names are for private network units or are planned generation that is not public.SharylandDC TieHidalgo Other South150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0DC-Ties1,106.0 1,106.0 1,106.0 1,106.0 1,106.0 1,106.0 1,106.0 1,106.0 1,106.0 1,106.0Kiamichi Energy Facility 1CT101 KMCHI_1CT101Fannin GasNorth2003 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0Kiamichi Energy Facility 1CT201 KMCHI_1CT201Fannin GasNorth2003 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0Kiamichi Energy Facility 1ST KMCHI_1STFannin Gas North2003 307.0 307.0 307.0 307.0 307.0 307.0 307.0 307.0 307.0 307.0Kiamichi Energy Facility 2CT101 KMCHI_2CT101Fannin GasNorth2003 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0Kiamichi Energy Facility 2CT201 KMCHI_2CT201Fannin GasNorth2003 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0Kiamichi Energy Facility 2ST KMCHI_2STFannin Gas North2003 307.0 307.0 307.0 307.0 307.0 307.0 307.0 307.0 307.0 307.0Tenaska-Frontier 1FTR_FTR_G1Grimes Gas North2000 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0Tenaska-Frontier 2FTR_FTR_G2Grimes Gas North2000 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0Tenaska-Frontier 3FTR_FTR_G3Grimes Gas North2000 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0 180.0Tenaska-Frontier 4FTR_FTR_G4Grimes Gas North2000 390.0 390.0 390.0 390.0 390.0 390.0 390.0 390.0 390.0 390.0Tenaska-Gateway 1TGCCS_CT1Rusk Gas North2001 162.0 162.0 162.0 162.0 162.0 162.0 162.0 162.0 162.0 162.0Tenaska-Gateway 2TGCCS_CT2Rusk Gas North2001 179.0 179.0 179.0 179.0 179.0 179.0 179.0 179.0 179.0 179.0Tenaska-Gateway 3TGCCS_CT3Rusk Gas North2001 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0 178.0Tenaska-Gateway 4TGCCS_UNIT4Rusk Gas North2001 389.0 389.0 389.0 389.0 389.0 389.0 389.0 389.0 389.0 389.0Switchable Resources3,168.0 3,168.0 3,168.0 3,168.0 3,168.0 3,168.0 3,168.0 3,168.0 3,168.0 3,168.0Kunitz WindKUNITZ_WIND_LGE Culberson Wind West199539.8 39.8 39.8 39.8 39.8 39.8 39.8 39.8 39.8 39.8Texas Big SpringSGMTN_SIGNALMT Howard Wind West199934.3 34.3 34.3 34.3 34.3 34.3 34.3 34.3 34.3 34.3West Texas Wind EnergySW_MESA_SW_MESA Upton Wind West199974.2 74.2 74.2 74.2 74.2 74.2 74.2 74.2 74.2 74.2Indian Mesa Wind FarmINDNNWP_INDNNWP Pecos Wind West200182.5 82.5 82.5 82.5 82.5 82.5 82.5 82.5 82.5 82.5King Mountain NEKING_NE_KINGNEUpton Wind West200179.3 79.3 79.3 79.3 79.3 79.3 79.3 79.3 79.3 79.3King Mountain NWKING NW KINGNWUptonWindWest200179 379 379 379 379 379 379 379 379 379 3KingMountainNWKING_NW_KINGNW..........King Mountain SEKING_SE_KINGSEUpton Wind West200140.3 40.3 40.3 40.3 40.3 40.3 40.3 40.3 40.3 40.3King Mountain SWKING_SW_KINGSW Upton Wind West200179.3 79.3 79.3 79.3 79.3 79.3 79.3 79.3 79.3 79.3Pecos Wind (Woodward 1) WOODWRD1_WOODWRD1 Pecos Wind West200182.5 82.5 82.5 82.5 82.5 82.5 82.5 82.5 82.5 82.5Pecos Wind (Woodward 2) WOODWRD2_WOODWRD2 Pecos Wind West200177.2 77.2 77.2 77.2 77.2 77.2 77.2 77.2 77.2 77.2Trent Wind FarmTRENT_TRENTNolan Wind West2001150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0Desert Sky Wind Farm 1INDNENR_INDNENR Pecos Wind West200284.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0Desert Sky Wind Farm 2INDNENR_INDNENR_2 Pecos Wind West200276.5 76.5 76.5 76.5 76.5 76.5 76.5 76.5 76.5 76.5Green Mountain Energy 1BRAZ_WND_WND1 Scurry Wind West200399.0 99.0 99.0 99.0 99.0 99.0 99.0 99.0 99.0 99.0Green Mountain Energy 2BRAZ_WND_WND2 Scurry Wind West200361.0 61.0 61.0 61.0 61.0 61.0 61.0 61.0 61.0 61.0Sweetwater Wind 1SWEETWND_WND1 Nolan Wind West200336.6 36.6 36.6 36.6 36.6 36.6 36.6 36.6 36.6 36.6Callahan WindCALLAHAN_WND1Callahan Wind West2004114.0 114.0 114.0 114.0 114.0 114.0 114.0 114.0 114.0 114.0Sweetwater Wind 3SWEETWN2_WND2 Nolan Wind West200497.5 97.5 97.5 97.5 97.5 97.5 97.5 97.5 97.5 97.5Horse Hollow Wind 1H_HOLLOW_WND1 Taylor Wind West2005213.0 213.0 213.0 213.0 213.0 213.0 213.0 213.0 213.0 213.0Sweetwater Wind 4SWEETWN3_WND3 Nolan Wind West2005129.0 129.0 129.0 129.0 129.0 129.0 129.0 129.0 129.0 129.0Buffalo Gap Wind Farm 1BUFF_GAP_UNIT1Taylor Wind West2006120.6 120.6 120.6 120.6 120.6 120.6 120.6 120.6 120.6 120.6Horse Hollow Wind 2HHOLLOW2_WIND1 Taylor Wind West2006184.0 184.0 184.0 184.0 184.0 184.0 184.0 184.0 184.0 184.0Horse Hollow Wind 3HHOLLOW3_WND_1 Taylor Wind West2006223.5 223.5 223.5 223.5 223.5 223.5 223.5 223.5 223.5 223.5Horse Hollow Wind 4HHOLLOW4_WND1 Taylor Wind West2006115.0 115.0 115.0 115.0 115.0 115.0 115.0 115.0 115.0 115.0Mesquite WindLNCRK_G83Shackelford Wind West2006200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0 200.0Red CanyonRDCANYON_RDCNY1 Borden Wind West200684.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0 84.0Sweetwater Wind 2SWEETWN2_WND24 Nolan Wind West200615.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9Barton Chapel WindBRTSW_BCW1Jack Wind North2007120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0 120.0Unit NameUnit CodeCounty FuelForecastZone2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Units used in determining the generation resources in the Winter SummaryUnit Capacities - WinterOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. This list includes MW available to the grid from private network (self-serve) units. It also includes distributedgeneration units that have registered with ERCOT. Data without unit names are for private network units or are planned generation that is not public.Buffalo Gap Wind Farm 2BUFF_GAP_UNIT2Taylor Wind West2007232.5 232.5 232.5 232.5 232.5 232.5 232.5 232.5 232.5 232.5Camp Springs 1CSEC_CSECG1Scurry Wind West2007134.4 134.4 134.4 134.4 134.4 134.4 134.4 134.4 134.4 134.4Camp Springs 2CSEC_CSECG2Scurry Wind West2007123.6 123.6 123.6 123.6 123.6 123.6 123.6 123.6 123.6 123.6Capricorn Ridge Wind 1CAPRIDGE_CR1Sterling Wind West2007214.5 214.5 214.5 214.5 214.5 214.5 214.5 214.5 214.5 214.5Capricorn Ridge Wind 3CAPRIDGE_CR2Sterling Wind West2007149.5 149.5 149.5 149.5 149.5 149.5 149.5 149.5 149.5 149.5Forest Creek Wind FarmMCDLD_FCW1Glasscock Wind West2007124.2 124.2 124.2 124.2 124.2 124.2 124.2 124.2 124.2 124.2Post Oak Wind 1LNCRK2_G871Shackelford Wind West2007100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0Post Oak Wind 2LNCRK2_G872Shackelford Wind West2007100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0Snyder Wind FarmENAS_ENA1Scurry Wind West200763.0 63.0 63.0 63.0 63.0 63.0 63.0 63.0 63.0 63.0Sweetwater Wind 5SWEETWN4_WND5 Nolan Wind West200779.2 79.2 79.2 79.2 79.2 79.2 79.2 79.2 79.2 79.2Sweetwater Wind 6SWEETWN4_WND4B Nolan Wind West2007103.7 103.7 103.7 103.7 103.7 103.7 103.7 103.7 103.7 103.7Sweetwater Wind 7SWEETWN4_WND4A Nolan Wind West2007117.8 117.8 117.8 117.8 117.8 117.8 117.8 117.8 117.8 117.8Whirlwind EnergyWEC_WECG1Floyd Wind West200760.0 60.0 60.0 60.0 60.0 60.0 60.0 60.0 60.0 60.0Wolfe FlatsDG_TURL_UNIT1HallWind West200710.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0 10.0Buffalo Gap Wind Farm 3BUFF_GAP_UNIT3Taylor Wind West2008170.2 170.2 170.2 170.2 170.2 170.2 170.2 170.2 170.2 170.2Capricorn Ridge Wind 2CAPRIDGE_CR3Sterling Wind West2008186.0 186.0 186.0 186.0 186.0 186.0 186.0 186.0 186.0 186.0Capricorn Ridge Wind 4CAPRIDG4_CR4Sterling Wind West2008112.5 112.5 112.5 112.5 112.5 112.5 112.5 112.5 112.5 112.5Champion Wind FarmCHAMPION_UNIT1Nolan Wind West2008126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5 126.5Elbow Creek Wind Project ELB_ELBCREEKHoward Wind West2008122.0 122.0 122.0 122.0 122.0 122.0 122.0 122.0 122.0 122.0Goat WindGOAT_GOATWIND Sterling Wind West200880.0 80.0 80.0 80.0 80.0 80.0 80.0 80.0 80.0 80.0Hackberry Wind FarmHWF_HWFG1Shackelford Wind West2008166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0 166.0Inadale WindINDL_INADALE1Nolan Wind West2008197.0 197.0 197.0 197.0 197.0 197.0 197.0 197.0 197.0 197.0McAdoo Wind FarmMWEC_G1Dickens Wind West2008150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0Ocotillo Wind FarmOWF_OWFHoward Wind West200858.8 58.8 58.8 58.8 58.8 58.8 58.8 58.8 58.8 58.8Panther Creek 1PC NORTH PANTHER1HowardWindWest2008142 5142 5142 5142 5142 5142 5142 5142 5142 5142 5PantherCreek1PC_NORTH_PANTHER1..........Panther Creek 2PC_SOUTH_PANTHER2 Howard Wind West2008115.5 115.5 115.5 115.5 115.5 115.5 115.5 115.5 115.5 115.5Pyron Wind FarmPYR_PYRON1Scurry Wind West2008249.0 249.0 249.0 249.0 249.0 249.0 249.0 249.0 249.0 249.0Roscoe Wind FarmTKWSW1_ROSCOE Nolan Wind West2008209.0 209.0 209.0 209.0 209.0 209.0 209.0 209.0 209.0 209.0Sand Bluff Wind FarmMCDLD_SBW1Glasscock Wind West200890.0 90.0 90.0 90.0 90.0 90.0 90.0 90.0 90.0 90.0Sherbino IKEO_KEO_SM1Pecos Wind West2008150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0Silver StarFLTCK_SSIEastland Wind North200860.0 60.0 60.0 60.0 60.0 60.0 60.0 60.0 60.0 60.0South Trent Wind FarmSTWF_T1Nolan Wind West2008101.2 101.2 101.2 101.2 101.2 101.2 101.2 101.2 101.2 101.2Stanton Wind EnergySWEC_G1Martin Wind West2008123.6 123.6 123.6 123.6 123.6 123.6 123.6 123.6 123.6 123.6TSTC West Texas WindDG_ROSC2_1UNIT Nolan Wind West20082.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0Turkey Track Wind Energy Center TTWEC_G1Nolan Wind West2008175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0 175.0Wolfe RidgeWHTTAIL_WR1Cooke Wind North2008112.5 112.5 112.5 112.5 112.5 112.5 112.5 112.5 112.5 112.5Bull Creek Wind PlantBULLCRK_WND1Borden Wind West200989.0 89.0 89.0 89.0 89.0 89.0 89.0 89.0 89.0 89.0Bull Creek Wind PlantBULLCRK_WND2Borden Wind West200991.0 91.0 91.0 91.0 91.0 91.0 91.0 91.0 91.0 91.0Horse Hollow Wind 1HHGT_HHOLLOW1 Kendall Wind South20090.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Horse Hollow Wind 2HHGT_HHOLLOW2 Kendall Wind South20090.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Horse Hollow Wind 3HHGT_HHOLLOW3 Kendall Wind South20090.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Horse Hollow Wind 4HHGT_HHOLLOW4 Kendall Wind South20090.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Horse Hollow Wind Callahan HHGT_CALLAHANKendall Wind South20090.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0Langford Wind PowerLGD_LANGFORDTom Green Wind West2009150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0Loraine Windpark ILONEWOLF_G1Mitchell Wind West200950.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0Loraine Windpark IILONEWOLF_G2Mitchell Wind West200951.0 51.0 51.0 51.0 51.0 51.0 51.0 51.0 51.0 51.0Loraine Windpark IIILONEWOLF_G3Mitchell Wind West201126.0 26.0 26.0 26.0 26.0 26.0 26.0 26.0 26.0 26.0Unit NameUnit CodeCounty FuelForecastZone2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Units used in determining the generation resources in the Winter SummaryUnit Capacities - WinterOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. This list includes MW available to the grid from private network (self-serve) units. It also includes distributedgeneration units that have registered with ERCOT. Data without unit names are for private network units or are planned generation that is not public.Loraine Windpark IVLONEWOLF_G4Mitchell Wind West201124.0 24.0 24.0 24.0 24.0 24.0 24.0 24.0 24.0 24.0Notrees-1NWF_NWF1Winkler Wind West2009152.6 152.6 152.6 152.6 152.6 152.6 152.6 152.6 152.6 152.6Panther Creek 3PC_SOUTH_PANTHER3 Howard Wind West2009199.5 199.5 199.5 199.5 199.5 199.5 199.5 199.5 199.5 199.5Papalote Creek Wind Farm PAP1_PAP1San Patricio Wind South2009179.9 179.9 179.9 179.9 179.9 179.9 179.9 179.9 179.9 179.9Penascal WindPENA_UNIT1Kenedy Wind South2009160.8 160.8 160.8 160.8 160.8 160.8 160.8 160.8 160.8 160.8Penascal WindPENA_UNIT2Kenedy Wind South2009141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6Cedro Hill WindCEDROHIL_CHW1Webb Wind South2010150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0 150.0Delaware Mountain Wind Farm KUNITZ_WIND_NWP Culberson Wind West201028.5 28.5 28.5 28.5 28.5 28.5 28.5 28.5 28.5 28.5Goat Wind 2GOAT_GOATWIN2Sterling Wind West201069.6 69.6 69.6 69.6 69.6 69.6 69.6 69.6 69.6 69.6Gulf Wind ITGW_T1Kenedy Wind South2010141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6Gulf Wind IITGW_T2Kenedy Wind South2010141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6 141.6Papalote Creek WindCOTTON_PAP2San Patricio Wind South2010200.1 200.1 200.1 200.1 200.1 200.1 200.1 200.1 200.1 200.1Penascal WindPENA_UNIT3Kenedy Wind South2010100.8 100.8 100.8 100.8 100.8 100.8 100.8 100.8 100.8 100.8WIND9,452 9,452 9,452 9,452 9,452 9,452 9,452 9,452 9,452 9,452Atkins 3ATKINS_ATKINSG3 Brazos Gas North12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0 12.0Atkins 4ATKINS_ATKINSG4 Brazos Gas North22.0 22.0 22.0 22.0 22.0 22.0 22.0 22.0 22.0 22.0Atkins 5ATKINS_ATKINSG5 Brazos Gas North25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0 25.0Atkins 6ATKINS_ATKINSG6 Brazos Gas North50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0AES DeepwaterAPD_APD_G1Harris Other Houston138.0 138.0 138.0 138.0 138.0 138.0 138.0 138.0 138.0 138.0C E Newman 5NEWMAN_NEWMA_5 Dallas Gas North37.0 37.0 37.0 37.0 37.0 37.0 37.0 37.0 37.0 37.0Leon Creek 3LEON_CRK_LCP3G3 Bexar Gas South56.0 56.0 56.0 56.0 56.0 56.0 56.0 56.0 56.0 56.0Leon Creek 4LEON_CRK_LCP4G4 Bexar Gas South88.0 88.0 88.0 88.0 88.0 88.0 88.0 88.0 88.0 88.0North Texas 1NTX_NTX_1Parker Gas North18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0 18.0N th T 2NTX NTX 2P kGN th18 018 018 018 018 018 018 018 018 018 0NorthTexas2NTX_NTX_2arerasor..........North Texas 3NTX_NTX_3Parker Gas North39.0 39.0 39.0 39.0 39.0 39.0 39.0 39.0 39.0 39.0Permian Basin 6PBSES_UNIT6Ward Gas West515.0 515.0 515.0 515.0 515.0 515.0 515.0 515.0 515.0 515.0Sam Bertron 1SRB_SRB_G1Harris Gas Houston174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0Sam Bertron 2SRB_SRB_G2Harris Gas Houston174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0Spencer 4SPNCER_SPNCE_4 Denton Gas North61.0 61.0 61.0 61.0 61.0 61.0 61.0 61.0 61.0 61.0Spencer 5SPNCER_SPNCE_5 Denton Gas North61.0 61.0 61.0 61.0 61.0 61.0 61.0 61.0 61.0 61.0Valley 1VLSES_UNIT1Fannin Gas North174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0 174.0Valley 2VLSES_UNIT2Fannin Gas North520.0 520.0 520.0 520.0 520.0 520.0 520.0 520.0 520.0 520.0Valley 3VLSES_UNIT3Fannin Gas North375.0 375.0 375.0 375.0 375.0 375.0 375.0 375.0 375.0 375.0Mothballed Resources2,557.0 2,557.0 2,557.0 2,557.0 2,557.0 2,557.0 2,557.0 2,557.0 2,557.0 2,557.0Nacogdoches Project09INR0007Nacogdoches Biomass-100.0 100.0 100.0 100.0 100.0 100.0100.0100.0 100.0Sandy Creek 109INR0001McLennan Coal-925.0 925.0 925.0 925.0 925.0 925.0925.0925.0 925.0CFB Power Plant Units 11&12 09INR0029Calhoun Coal260.0260.0 260.0 260.0 260.0 260.0 260.0260.0260.0 260.0Coleto Creek Unit 214INR0002Goliad Coal-- - - - -660.0660.0660.0 660.0Panda Temple Power10INR0020bBellGas-- - -780.0 780.0 780.0780.0780.0 780.0Panda Temple Power10INR0020aBellGas-- -780.0 780.0 780.0 780.0780.0780.0 780.0Jack County 210INR0010Jack Gas565.0565.0 565.0 565.0 565.0 565.0 565.0565.0565.0 565.0Pondera King Power Project 10INR0022Harris Gas-- - -1,380.0 1,380.0 1,380.0 1,380.0 1,380.0 1,380.0Las Brisas Energy Center12INR0016aNueces Other-- - -620.0 620.0 620.0620.0620.0 620.0Las Brisas Energy Center12INR0016bNueces Other--- - -620.0 620.0620.0620.0 620.0Unit NameUnit CodeCounty FuelForecastZone2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Units used in determining the generation resources in the Winter SummaryUnit Capacities - WinterOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. This list includes MW available to the grid from private network (self-serve) units. It also includes distributedgeneration units that have registered with ERCOT. Data without unit names are for private network units or are planned generation that is not public.RRE Austin Solar11INR0086Travis Solar-60 60 60 60 60 60 60 60 60FRV AE Solar10INR0082Travis Solar-30.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0 30.0New Units with Signed IA and Air Permit825.01,940.0 1,940.0 2,720.0 5,500.0 6,120.0 6,780.0 6,780.0 6,780.0 6,780.0Gunsight Mountain08INR0018Howard Wind--120.0 120.0 120.0 120.0 120.0120.0120.0 120.0Los Vientos11INR0033Cameron Wind--400.0 400.0 400.0 400.0 400.0400.0400.0 400.0Archer-Young08INR0062Young Wind-250.0 250.0 250.0 250.0 250.0 250.0250.0250.0 250.0Penascal Wind Farm 306INR0022cKenedy Wind-- -202.0 202.0 202.0 202.0202.0202.0 202.0Sherbino Mesa Wind Farm 2 06INR0012bPecos Wind150.0150.0 150.0 150.0 150.0 150.0 150.0150.0150.0 150.0WKN Mozart09INR0061Kent Wind-- 30.0 30.0 30.0 30.0 30.0 30.0 30.030.0Magic Valley Wind Project 10INR0060Willacy Wind-202.0 202.0 202.0 202.0 202.0 202.0202.0202.0 202.0Senate Wind Project08INR0011Jack Wind-150.0 150.0 150.0 150.0 150.0 150.0150.0150.0 150.0New Wind Generation150.0752.0 1,302.0 1,504.0 1,504.0 1,504.0 1,504.0 1,504.0 1,504.0 1,504.0Pampa Energy Center07INR0004Gray Coal-165.0 165.0 165.0 165.0 165.0 165.0165.0165.0 165.0White Stallion Energy Center 14INR0005Matagorda Coal-- -1,200.0 1,200.0 1,200.0 1,200.0 1,200.0 1,200.0 1,200.0Comanche Peak 3 and 415INR0002Somervel Nuclear-- - - - - - -3,200.0 3,200.0STP 3 and 415INR0008Matagorda Nuclear-- - - -2,700.0 2,700.0 2,700.0 2,700.0 2,700.0Potential Public Non-Wind Resources-165.0 165.0 1,365.0 1,365.0 4,065.0 4,065.0 4,065.0 7,265.0 7,265.0Throckmorton Wind Farm12INR0003Throckmorton Wind-400.0 400.0 400.0 400.0 400.0 400.0400.0400.0400.0Buffalo Gap 4 and 508INR0065Nolan Wind-465.0 465.0 465.0 465.0 465.0 465.0465.0465.0 465.02W Whatley Phase 111INR0084Ector Wind-45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0 45.0B&B Panhandle Wind09INR0024Carson Wind-1,001.0 1,001.0 1,001.0 1,001.0 1,001.0 1,001.0 1,001.0 1,001.0 1,001.0Fort Concho Wind Farm12INR0004Tom GreenWind400 0400 0400 0400 0400 0400 0400 0400 0400 0FortConchoWindFarm12INR0004TomGreen-.........Scurry County Wind III09INR0037Scurry Wind-350.0 350.0 350.0 350.0 350.0 350.0350.0350.0 350.0M Bar Wind08INR0038Andrews Wind-194.0 194.0 194.0 194.0 194.0 194.0194.0194.0 194.0Gatesville Wind Farm09INR0034Coryell Wind-200.0 200.0 200.0 200.0 200.0 200.0200.0200.0 200.0Pistol Hill Energy Center08INR0025Ector Wind-300.0 300.0 300.0 300.0 300.0 300.0300.0300.0 300.02W Whatley Phase 212INR0043Ector Wind--290.0 290.0 290.0 290.0 290.0290.0290.0 290.0Potential Public Wind Resources-3,355.0 3,645.0 3,645.0 3,645.0 3,645.0 3,645.0 3,645.0 3,645.0 3,645.011INR0037Smith Biomass-50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.0 50.014INR0003Nolan Coal-- -850.0 850.0 850.0 850.0850.0850.0 850.011INR0075Fort Bend Coal-15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.010INR0032Navarro Gas-775.0 775.0 775.0 775.0 775.0 775.0775.0775.0 775.010INR0029Hood Gas-810.0 810.0 810.0 810.0 810.0 810.0810.0810.0 810.011INR0040Freestone Gas-640.0 640.0 640.0 640.0 640.0 640.0640.0640.0 640.011INR0006Lamar Gas-579.0 579.0 579.0 579.0 579.0 579.0579.0579.0 579.009INR0031Ector Gas-275.0 275.0 275.0 275.0 275.0 275.0275.0275.0 275.009INR0050Fannin Gas-1,200.0 1,200.0 1,200.0 1,200.0 1,200.0 1,200.0 1,200.0 1,200.0 1,200.012INR0007Lamar Gas-296.0 296.0 296.0 296.0 296.0 296.0296.0296.0 296.010INR0021Grayson Gas-646.0 646.0 646.0 646.0 646.0 646.0646.0646.0 646.010INR0018Madison Gas-550 550 550 550 550 550 550 550 55013INR0021Llano Gas-- --600 600 600 600 600 60013INR0028Hale Gas-- - 392 392 392 392 392 392 39213INR0023Ector Gas-- 240 240 240 240 240 240 240 240Unit NameUnit CodeCounty FuelForecastZone2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Units used in determining the generation resources in the Winter SummaryUnit Capacities - WinterOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. This list includes MW available to the grid from private network (self-serve) units. It also includes distributedgeneration units that have registered with ERCOT. Data without unit names are for private network units or are planned generation that is not public.11INR0049 Wharton Gas -275 275 275 275 275 275 275 275 27511INR0071 Harris Gas -7 7 7 7 7 7 7 7 716INR0002 Brazoria Other -- - - - - 700 700 700 70010INR0089 Harris Other -40 40 40 40 40 40 40 40 4010INR0080 Presidio Solar -144 144 144 144 144 144 144 144 14410INR0085 Ector Solar -40 40 40 40 40 40 40 40 4011INR0094 Kent Solar -100 100 100 100 100 100 100 100 10012INR0057 Ector Solar --40 40 40 40 40 40 40 4011INR0090Howard Solar-60 60 60 60 60 60 60 60 6015INR0011bBorden Solar-- - - -38 38 38 38 3811INR0070Reeves Solar-50 50 50 50 50 50 50 50 5011INR0061Presidio Solar-90 90 90 90 90 90 90 90 9011INR0060Tom Green Solar-90 90 90 90 90 90 90 90 9011INR0058Pecos Solar-135 135 135 135 135 135 135 135 135Potential Non-Public Non-Wind Resources-6,867.0 7,147.0 8,389.0 8,989.0 9,027.0 9,727.0 9,727.0 9,727.0 9,727.007INR0013Coke Wind-200 200 200 200 200 200 200 200 20008INR0019aGray Wind-- - 250 250 250 250 250 250 25008INR0019bGray Wind-- - 250 250 250 250 250 250 25008INR0019cGray Wind-- - 250 250 250 250 250 250 25008INR0020Eastland Wind-200 200 200 200 200 200 200 200 20008INR0031Childress Wind-100 100 100 100 100 100 100 100 10008INR0041Coke Wind-- 200 200 200 200 200 200 200 20008INR0042Coke Wind-- 200 200 200 200 200 200 200 20008INR0049ClayWind505050505050505008INR0049--09INR0025 Concho Wind -- 180 180 180 180 180 180 180 18009INR0041 Mitchell Wind -- 300 300 300 300 300 300 300 30009INR0048 Jack Wind -100.0 100.0 100.0 100.0 100.0 100.0 100 100 10009INR0051 Borden Wind -0 249 249 249 249 249 249 249 24909INR0054Stonewall Wind-148.5 148.5 148.5 148.5 148.5 148.5 148.5 148.5 148.509INR0058Howard Wind-0 250 250 250 250 250 250 250 25009INR0073Scurry Wind-0 0 200 200 200 200 200 200 20009INR0074Motley Wind-70 70 70 70 70 70 70 70 7009INR0077Reagan Wind-0 0 500 500 500 500 500 500 50010INR0008Pecos Wind-500 500 500 500 500 500 500 500 50010INR0009Castro Wind-0 0 300 300 300 300 300 300 30010INR0013Upton Wind-400 400 400 400 400 400 400 400 40010INR0015Mitchell Wind-0 0 350 350 350 350 350 350 35010INR0016Childress Wind-150 150 150 150 150 150 150 150 15010INR0019Deaf Smith Wind-609 609 609 609 609 609 609 609 60910INR0023Haskell Wind-386 386 386 386 386 386 386 386 38610INR0024Briscoe Wind-0 2940 2940 2940 2940 2940 2940 2940 294010INR0033Armstrong Wind-399 399 399 399 399 399 399 399 39910INR0041Floyd Wind-135 135 135 135 135 135 135 135 13510INR0042Mason Wind-170 170 170 170 170 170 170 170 17010INR0048Hardeman Wind-1000 1000 1000 1000 1000 1000 1000 1000 100010INR0051Brazoria Wind-200 200 200 200 200 200 200 200 200Unit NameUnit CodeCounty FuelForecastZone2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Units used in determining the generation resources in the Winter SummaryUnit Capacities - WinterOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. This list includes MW available to the grid from private network (self-serve) units. It also includes distributedgeneration units that have registered with ERCOT. Data without unit names are for private network units or are planned generation that is not public.10INR0052a Knox Wind -21 21 21 21 21 21 21 21 2110INR0054Palo Pinto Wind-36 36 36 36 36 36 36 36 3610INR0056Borden Wind-0 249 249 249 249 249 249 249 24910INR0062aPecos Wind-80 80 80 80 80 80 80 80 8010INR0062bPecos Wind-0 220 220 220 220 220 220 220 22010INR0077Callahan Wind-0 101 101 101 101 101 101 101 10110INR0079Nolan Wind-60 60 60 60 60 60 60 60 6010INR0081aClay Wind-30.4 30.4 30.4 30.4 30.4 30.4 30.4 30.4 30.410INR0081bClay Wind-19.2 19.2 19.2 19.2 19.2 19.2 19.2 19.2 19.211INR0013Mills Wind-0 0 150 150 150 150 150 150 15011INR0019Upton Wind-200 200 200 200 200 200 200 200 20011INR0025Crockett Wind-400 400 400 400 400 400 400 400 40011INR0029Throckmorton Wind-200 200 200 200 200 200 200 200 20011INR0039Starr Wind-201 201 201 201 201 201 201 201 20111INR0043Coke Wind-300 300 300 300 300 300 300 300 30011INR0047Deaf Smith Wind-600 600 600 600 600 600 600 600 60011INR0050Crosby Wind-149 149 149 149 149 149 149 149 14911INR0054San Patricio Wind-161 161 161 161 161 161 161 161 16111INR0057Cameron Wind-165 165 165 165 165 165 165 165 16511INR0062Nueces Wind-149 149 149 149 149 149 149 149 14911INR0065Nueces Wind-240 240 240 240 240 240 240 240 24011INR0067Cameron Wind-0 78 78 78 78 78 78 78 7811INR0076Archer Wind-94 94 94 94 94 94 94 94 9411INR0079aClay Wind-200 200 200 200 200 200 200 200 20011INR0081Live OakWind0727272727272727211INR0081LiveOak-11INR0082AVal Verde Wind-0 0 50 50 50 50 50 50 5011INR0082BVal Verde Wind-0 150 150 150 150 150 150 150 15011INR0083ACrockett Wind-0 0 50 50 50 50 50 50 5011INR0083BCrockett Wind-0 100 100 100 100 100 100 100 10011INR0085Nolan Wind-106 106 106 106 106 106 106 106 10611INR0091Webb Wind-92 92 92 92 92 92 92 92 9212INR0002aBriscoe Wind-0 0 200 200 200 200 200 200 20012INR0002bBriscoe Wind-0 0 0 200 200 200 200 200 20012INR0002cBriscoe Wind-0 0 0 0 350 350 350 350 35012INR0005Floyd Wind-0 1100 1100 1100 1100 1100 1100 1100 110012INR0018Gray Wind-0 500 500 500 500 500 500 500 50012INR0026Randall Wind-0 400 400 400 400 400 400 400 40012INR0027Gray Wind-0 200 200 200 200 200 200 200 20012INR0029Swisher Wind-0 500 500 500 500 500 500 500 50012INR0033Motley Wind-150 150 150 150 150 150 150 150 15012INR0034Borden Wind-0 342 342 342 342 342 342 342 34212INR0035Nueces Wind-0 249 249 249 249 249 249 249 24912INR0042Deaf Smith Wind-400 400 400 400 400 400 400 400 40012INR0045Kleberg Wind-135 135 135 135 135 135 135 135 13512INR0053Crockett Wind-615 615 615 615 615 615 615 615 61512INR0072Kinney Wind-0 100 100 100 100 100 100 100 10012INR0075Wilbarger Wind-499 499 499 499 499 499 499 499 499Unit NameUnit CodeCounty FuelForecastZone2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Units used in determining the generation resources in the Winter SummaryUnit Capacities - WinterOperational capacities are based on unit testing. Other capacities are based on information provided by the plant owners. This list includes MW available to the grid from private network (self-serve) units. It also includes distributedgeneration units that have registered with ERCOT. Data without unit names are for private network units or are planned generation that is not public.13INR0004 Deaf Smith Wind -0 0 500 500 500 500 500 500 50013INR0005Carson Wind-0 0 600 600 600 600 600 600 60013INR0006Gray Wind-0 0 750 750 750 750 750 750 75013INR0007Pecos Wind-0 0 200 200 200 200 200 200 20013INR0010aParmer Wind-0 200 200 200 200 200 200 200 20013INR0010bParmer Wind-0 0 500 500 500 500 500 500 50013INR0010cParmer Wind-0 0 0 500 500 500 500 500 50013INR0016Deaf Smith Wind-0 0 250.5 250.5 250.5 250.5 250.5 250.5 250.513INR0017Childress Wind-0 0 200 200 200 200 200 200 20013INR0020aGlasscock Wind-0 200 200 200 200 200 200 200 20013INR0020bGlasscock Wind-0 0 150 150 150 150 150 150 15013INR0025Randall Wind-0 0 150 150 150 150 150 150 15013INR0026Oldham Wind-0 0 201 201 201 201 201 201 20113INR0036Hidalgo Wind-0 200 200 200 200 200 200 200 20014INR0001Pecos Wind-0 0 0 500 500 500 500 500 50014INR0006Floyd Wind-0 0 0 151 151 151 151 151 15115INR0011aBorden Wind-0 0 0 0 112 112 112 112 112Potential Non-Public Wind Resources-0 0 0 0 0 0 0 0 0-10,070.119,400.1 25,451.6 26,802.6 27,264.6 27,264.6 27,264.6 27,264.6 27,264.6Long-Term ProjectionsMWERCOT GENERATION CAPACITY AND DEMAND PROJECTIONS96,750104,865100 000110,000120,000Total Requirement (Peak + 13.75% Reserve Margin)Peak demandCapacity less units 50 years old or olderCapacity less units 40 years old or olderCapacity less units 30 years old or older08 081,47789,26378,47385,05592,18980,00090,000100,00070,85062,28671,62870,88269,36265,09357 74065,09357,74060,00070,00057,74048,77748,77743,49537,41948,77743,49537,41935,44030 00040,00050,00021,92920,00030,00020112016202120262031Long-Term Projections90,000MWPOSSIBLE ERCOT GENERATION CAPACITY NEEDED(including reserve margin)77,97570,00080,000Capacity needed less units 30 years old or olderCapacity needed less units 40 years old or olderCapacity needed less units 50 years old or older49,48158,47950,42462,48551,12750,00060,00037,42123,17638,12321 80836,17830,00040,0006,44521,80810,00020,00002016 2021 2026 2031Fuel Type 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Biomass94194194194194194194194194194Coal19,03419,95919,95919,95919,95919,95920,61920,61920,61920,619Natural Gas46,94347,66547,70548,50250,67950,69751,01451,01451,01451,014Nuclear5,1315,1315,1315,1315,1315,1315,1315,1315,1315,131Other6016016016016011,2211,8411,8411,8411,841Hydro537537537537537537537537537537Wind835888933953953953953953953953Solar-909090909090909090Total73,17475,06575,15075,96778,14478,78180,37880,37880,37880,378Fuel Type 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Biomass0.1% 0.3% 0.3% 0.3% 0.2% 0.2% 0.2% 0.2% 0.2% 0.2%Coal26.0% 26.6% 26.6% 26.3% 25.5% 25.3% 25.7% 25.7% 25.7% 25.7%Natural Gas64.2% 63.5% 63.5% 63.8% 64.9% 64.4% 63.5% 63.5% 63.5% 63.5%Nuclear7.0% 6.8% 6.8% 6.8% 6.6% 6.5% 6.4% 6.4% 6.4% 6.4%Other0.8% 0.8% 0.8% 0.8% 0.8% 1.5% 2.3% 2.3% 2.3% 2.3%Hydro0.7% 0.7% 0.7% 0.7% 0.7% 0.7% 0.7% 0.7% 0.7% 0.7%Wind1.1% 1.2% 1.2% 1.3% 1.2% 1.2% 1.2% 1.2% 1.2% 1.2%Solar0.0% 0.1% 0.1% 0.1% 0.1% 0.1% 0.1% 0.1% 0.1% 0.1%Summer Fuel Types - ERCOTFuel type is based on the primary fuel. Capacities of the wind units are included at 8.7%. The amounts available for the grid according to information fromthe owners of the private network (self-serve) units and the distributed generation units that have registered with ERCOT are included.In MWIn PercentagesFuel Type 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Biomass97197197197197197197197197197Coal19,19620,12120,12120,12120,12120,12120,78120,78120,78120,781Natural Gas50,344 50,374 50,364 51,144 53,304 53,304 53,621 53,621 53,621 53,621Nuclear5,1985,1985,1985,1985,1985,1985,1985,1985,1985,198Other6016016016011,2211,8411,8411,8411,8411,841Hydro537537537537537537537537537537Wind835888933953953953953953953953Solar-909090909090909090Total76,80878,00578,04178,84081,62082,24083,21783,21783,21783,217Fuel Type 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Biomass0.1% 0.3%0.3% 0.2% 0.2% 0.2% 0.2% 0.2% 0.2% 0.2%Coal25.0% 25.8% 25.8% 25.5% 24.7% 24.5% 25.0% 25.0% 25.0% 25.0%Natural Gas65.5% 64.6% 64.5% 64.9% 65.3% 64.8% 64.4% 64.4% 64.4% 64.4%Nuclear6.8% 6.7% 6.7% 6.6% 6.4% 6.3% 6.2% 6.2% 6.2% 6.2%Other0.8% 0.8% 0.8% 0.8% 1.5% 2.2% 2.2% 2.2% 2.2% 2.2%Hydro0.7% 0.7% 0.7% 0.7% 0.7% 0.7% 0.6% 0.6% 0.6% 0.6%Wind1.1% 1.1% 1.2% 1.2% 1.2% 1.2% 1.1% 1.1% 1.1% 1.1%Solar0.0% 0.1% 0.1% 0.1% 0.1% 0.1% 0.1% 0.1% 0.1% 0.1%Winter Fuel Types - ERCOTFuel type is based on the primary fuel. Capacities of the wind units are included at 8.7%. The amounts available for the grid according to information fromthe owners of the private network (self-serve) units and the distributed generation units that have registered with ERCOT are included.In MWIn PercentagesCounty2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Anderson135 138 141 144 146 148 150 152 154 156Andrews150 153 157 159 162 164 166 169 171 173Angelina238 243 249 253 257 260 265 268 272 275Aransas54 55 56 57 58 59 60 60 61 62Archer 24 24 25 25 26 26 27 27 27 28Atascosa 80 81 83 85 86 87 89 90 91 92Austin 91 93 96 97 99 100 102 103 104 105Bandera 57 58 59 60 61 62 63 64 65 65Bastrop 174 177 182 185 188 190 193 196 198 200Baylor5555555555Bee 57 58 60 61 62 63 64 65 65 66Bell 728 745 763 776 787 797 810 822 833 841Bexar 4,221 4,316 4,420 4,496 4,564 4,618 4,698 4,762 4,827 4,876Blanco 28 29 30 30 31 31 32 32 32 33Borden3333333333Bosque 52 53 54 55 56 57 58 59 59 60Brazoria 1,971 2,015 2,064 2,099 2,131 2,156 2,193 2,223 2,253 2,276Brazos 551 564 577 587 596 603 613 622 630 637Brewster 19 19 20 20 20 21 21 21 22 22Brooks 19 19 20 20 20 21 21 21 21 22Brown 114 117 120 122 124 125 127 129 131 132Burleson 30 31 32 32 33 33 34 34 35 35Burnet 124 126 129 132 134 135 138 139 141 143Caldwell 103 106 108 110 112 113 115 117 118 119Calhoun 85 87 89 91 92 93 95 96 97 98Callahan 42 43 44 44 45 45 46 47 48 48Cameron 685 701 718 730 741 750 763 773 784 792The loads shown are the projected coincident loads of the individual delivery points from the 2011 ALDRs and do not include self-serveloads. The ALDR values were used to compute a percentage of load by county, and the percentage was applied to the forecastedERCOT coincident peak. The values shown here are used in the Summer import/export calculations.Summer Load by CountySummer Load, MWCounty2011 2012 2013 2014 2015 2016 2017 2018 2019 2020The loads shown are the projected coincident loads of the individual delivery points from the 2011 ALDRs and do not include self-serveloads. The ALDR values were used to compute a percentage of load by county, and the percentage was applied to the forecastedERCOT coincident peak. The values shown here are used in the Summer import/export calculations.Summer Load by CountySummer Load, MWChambers 451 461 472 480 487 493 501 508 515 520Cherokee 91 93 96 97 99 100 102 103 104 105Childress 15 15 15 16 16 16 16 17 17 17Clay 25 25 26 26 27 27 28 28 28 29Coke 21 22 22 23 23 23 24 24 24 24Coleman 36 37 37 38 39 39 40 40 41 41Collin 2,280 2,330 2,387 2,428 2,465 2,494 2,537 2,571 2,607 2,633Colorado 80 82 84 85 87 88 89 90 91 92Comal 347 355 364 370 376 380 387 392 397 401Comanche 41 42 43 44 45 45 46 46 47 48Concho 13 13 13 14 14 14 14 14 15 15Cooke 126 129 132 134 136 138 140 142 144 145Coryell 107 109 112 114 115 117 119 120 122 123Cottle4444444555Crane 83 85 87 88 90 91 92 93 95 96Crockett 39 40 41 42 43 43 44 44 45 45Crosby2222222222Culberson5555556666Dallas 7,681 7,853 8,043 8,182 8,305 8,403 8,548 8,664 8,783 8,873Dawson 67 69 71 72 73 74 75 76 77 78Delta 12 12 12 12 13 13 13 13 13 13Denton 2,093 2,140 2,192 2,230 2,263 2,290 2,329 2,361 2,394 2,418Dewitt 71 72 74 75 77 77 79 80 81 82Dickens8888888999Dimmit 18 18 18 19 19 19 20 20 20 20Duval 47 48 49 50 50 51 52 53 53 54Eastland 58 59 61 62 63 63 65 65 66 67Ector 423 432 443 450 457 463 471 477 484 489County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020The loads shown are the projected coincident loads of the individual delivery points from the 2011 ALDRs and do not include self-serveloads. The ALDR values were used to compute a percentage of load by county, and the percentage was applied to the forecastedERCOT coincident peak. The values shown here are used in the Summer import/export calculations.Summer Load by CountySummer Load, MWEdwards9 9 9 9 9 10 10 10 10 10Ellis 582 595 609 620 629 637 648 656 666 672Erath 105 108 110 112 114 115 117 119 120 121Falls 47 48 49 50 50 51 52 53 53 54Fannin 72 73 75 77 78 79 80 81 82 83Fayette 78 80 82 83 85 86 87 88 90 90Fisher 24 24 25 25 25 26 26 27 27 27Floyd0000000000Foard3333334444Fort Bend 1,269 1,297 1,328 1,351 1,372 1,388 1,412 1,431 1,451 1,465Franklin3333333333Freestone 54 55 56 57 58 59 60 61 62 62Frio 33 34 35 35 36 36 37 37 38 38Galveston 1,381 1,411 1,446 1,471 1,493 1,510 1,536 1,557 1,579 1,595Gillespie 66 68 69 70 71 72 74 75 76 76Glasscock 19 20 20 20 21 21 21 22 22 22Goliad 21 22 22 23 23 23 24 24 24 25Gonzales 59 61 62 63 64 65 66 67 68 69Grayson 445 455 466 474 482 487 496 502 509 515Grimes 20 20 21 21 21 22 22 22 23 23Guadalupe 253 258 264 269 273 276 281 285 289 292Hall5555556666Hamilton 21 22 22 23 23 23 24 24 24 25Hardeman 16 17 17 17 18 18 18 18 19 19Harris 12,701 12,985 13,300 13,529 13,733 13,894 14,134 14,327 14,524 14,671Haskell 26 27 27 28 28 29 29 29 30 30Hays 431 441 452 459 466 472 480 486 493 498Henderson 161 164 168 171 174 176 179 181 184 186County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020The loads shown are the projected coincident loads of the individual delivery points from the 2011 ALDRs and do not include self-serveloads. The ALDR values were used to compute a percentage of load by county, and the percentage was applied to the forecastedERCOT coincident peak. The values shown here are used in the Summer import/export calculations.Summer Load by CountySummer Load, MWHidalgo 1,213 1,241 1,271 1,292 1,312 1,327 1,350 1,369 1,387 1,402Hill 98 100 103 104 106 107 109 110 112 113Hood 224 229 235 239 242 245 249 253 256 259Hopkins 112 114 117 119 121 122 125 126 128 129Houston 40 41 42 42 43 43 44 45 45 46Howard 114 117 119 121 123 125 127 129 130 132Hunt 242 248 254 258 262 265 270 273 277 280Irion 11 11 11 11 11 12 12 12 12 12Jack 22 23 23 23 24 24 25 25 25 25Jackson 37 37 38 39 40 40 41 41 42 42Jeff Davis4444444444Jim Hogg3333334444Jim Wells 84 86 88 89 91 92 93 95 96 97Johnson 344 352 361 367 372 377 383 388 394 398Jones 45 46 47 48 49 49 50 51 52 52Karnes 28 29 30 30 31 31 32 32 32 33Kaufman 284 290 297 303 307 311 316 320 325 328Kendall 102 104 107 109 110 112 114 115 117 118Kenedy1111112222Kent 54 56 57 58 59 60 61 61 62 63Kerr 133 136 139 142 144 146 148 150 152 154Kimble 15 15 15 16 16 16 16 17 17 17King8888888999Kinney6666666677Kleberg 75 77 79 80 81 82 84 85 86 87Knox 21 21 22 22 23 23 23 24 24 24La Salle 15 15 15 15 16 16 16 16 17 17Lamar 155 158 162 165 167 169 172 174 177 179County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020The loads shown are the projected coincident loads of the individual delivery points from the 2011 ALDRs and do not include self-serveloads. The ALDR values were used to compute a percentage of load by county, and the percentage was applied to the forecastedERCOT coincident peak. The values shown here are used in the Summer import/export calculations.Summer Load by CountySummer Load, MWLampasas 52 53 54 55 56 57 58 59 59 60Lavaca 38 39 40 41 41 42 42 43 44 44Lee 36 36 37 38 39 39 40 40 41 41Leon 62 64 65 66 67 68 69 70 71 72Limestone 66 68 69 70 71 72 74 75 76 76Live Oak 76 78 79 81 82 83 84 86 87 88Llano 69 71 72 74 75 76 77 78 79 80Loving8888999999Madison4455555555Martin 30 31 32 32 33 33 34 34 34 35Mason 12 12 13 13 13 13 13 14 14 14Matagorda 141 144 148 150 153 154 157 159 161 163Maverick 84 86 88 90 91 92 94 95 96 97Mcculloch 29 30 31 31 32 32 33 33 34 34Mclennan 720 736 754 767 779 788 802 813 824 832Mcmullen8888999999Medina 201 205 210 214 217 220 223 227 230 232Menard6666667777Midland 363 371 380 386 392 397 404 409 415 419Milam 67 69 70 72 73 74 75 76 77 78Mills 9 9 10 10 10 10 10 10 11 11Mitchell 21 22 22 23 23 23 24 24 25 25Montague 66 67 69 70 71 72 73 74 75 76Montgomery 229 235 240 244 248 251 255 259 262 265Motley4444444444Nacogdoches 164 167 172 174 177 179 182 185 187 189Navarro 188 192 197 200 203 205 209 212 215 217Nolan 56 57 59 60 61 61 62 63 64 65County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020The loads shown are the projected coincident loads of the individual delivery points from the 2011 ALDRs and do not include self-serveloads. The ALDR values were used to compute a percentage of load by county, and the percentage was applied to the forecastedERCOT coincident peak. The values shown here are used in the Summer import/export calculations.Summer Load by CountySummer Load, MWNueces 995 1,017 1,042 1,060 1,076 1,089 1,107 1,122 1,138 1,149Palo Pinto 85 87 89 91 92 93 95 96 97 98Parker 340 347 356 362 367 371 378 383 388 392Pecos 93 95 97 99 100 101 103 104 106 107Presidio 11 11 11 11 11 12 12 12 12 12Rains 26 26 27 27 28 28 29 29 29 30Reagan 16 16 17 17 17 18 18 18 18 19Real 11 11 11 11 11 12 12 12 12 12Red River 25 25 26 26 27 27 28 28 28 29Reeves 35 36 37 38 38 39 39 40 40 41Refugio 23 23 24 24 24 25 25 25 26 26Robertson 32 33 34 34 35 35 36 36 37 37Rockwall 256 262 268 273 277 280 285 289 293 296Runnels 32 33 33 34 35 35 36 36 37 37Rusk7778888888San Patricio 139 143 146 149 151 153 155 157 159 161San Saba 13 13 13 13 14 14 14 14 14 15Schleicher 14 14 15 15 15 15 15 16 16 16Scurry 111 114 116 118 120 122 124 125 127 128Shackelford 14 14 14 15 15 15 15 16 16 16Smith 601 614 629 640 650 657 669 678 687 694Somervell 28 28 29 29 30 30 31 31 32 32Starr 68 70 72 73 74 75 76 77 78 79Stephens 67 69 70 72 73 74 75 76 77 78Sterling 12 12 12 13 13 13 13 13 14 14Stonewall6667777777Sutton 18 18 19 19 19 20 20 20 20 21Tarrant 5,328 5,447 5,579 5,675 5,760 5,828 5,929 6,010 6,092 6,154County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020The loads shown are the projected coincident loads of the individual delivery points from the 2011 ALDRs and do not include self-serveloads. The ALDR values were used to compute a percentage of load by county, and the percentage was applied to the forecastedERCOT coincident peak. The values shown here are used in the Summer import/export calculations.Summer Load by CountySummer Load, MWTaylor 362 371 380 386 392 397 403 409 414 419Terrell2222222222Throckmorton8888899999Titus0000000000Tom Green 270 276 282 287 291 295 300 304 308 311Travis 2,547 2,604 2,667 2,713 2,754 2,786 2,834 2,873 2,912 2,942Upton 23 24 25 25 25 26 26 26 27 27Uvalde 54 55 57 58 59 59 60 61 62 63Val Verde 90 92 95 96 98 99 101 102 103 104Van Zandt 64 66 67 68 69 70 71 72 73 74Victoria 261 266 273 278 282 285 290 294 298 301Waller 198 202 207 211 214 216 220 223 226 228Ward 70 72 74 75 76 77 78 79 80 81Washington 117 119 122 124 126 128 130 132 134 135Webb 429 439 449 457 464 469 477 484 491 496Wharton 112 115 118 120 121 123 125 127 128 130Wichita 410 420 430 437 444 449 457 463 469 474Wilbarger 36 37 38 38 39 40 40 41 41 42Willacy 37 38 39 39 40 40 41 42 42 43Williamson 1,064 1,088 1,115 1,134 1,151 1,164 1,184 1,201 1,217 1,230Wilson 74 76 78 79 80 81 83 84 85 86Winkler 46 47 48 49 49 50 51 52 52 53Wise 209 213 219 222 226 228 232 235 239 241Wood7888888899Young 61 62 64 65 66 67 68 69 70 70Zapata 27 28 29 29 30 30 30 31 31 32Zavala 20 20 21 21 22 22 22 23 23 23County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Anderson----------Andrews----------Angelina45454545454545454545Aransas----------Archer----------Atascosa391391391391391391391391391391Austin----------Bandera----------Bastrop1,6561,6561,6561,6561,6561,6561,6561,6561,6561,656Baylor----------Bee----------Bell---780 1,5601,5601,5601,5601,5601,560Bexar4,7534,7534,7534,7534,7534,7534,7534,7534,7534,753Blanco----------Borden23232323232323232323Bosque813813813813813813813813813813Brazoria399399399399399399399399399399Brazos226226226226226226226226226226Brewster----------Brooks----------Brown----------Burleson----------Burnet102102102102102102102102102102Caldwell----------Calhoun353403403403403403403403403403Callahan10101010101010101010Cameron116116151151151151151151151151Chambers2,6682,6682,6682,6682,6682,6682,6682,6682,6682,668Cherokee673673673673673673673673673673These values are used in the summer import/export calculations for each county. Capacities for mothballed units are included asthe availablecapacity of the unit. Capacities for the wind units are at 8.7%. These values include the amount available for the grid according information from theowners of the private network units and the distributed generation units that have registered with ERCOT.Summer Generation by CountySummer Generation, MWCounty2011 2012 2013 2014 2015 2016 2017 2018 2019 2020These values are used in the summer import/export calculations for each county. Capacities for mothballed units are included asthe availablecapacity of the unit. Capacities for the wind units are at 8.7%. These values include the amount available for the grid according information from theowners of the private network units and the distributed generation units that have registered with ERCOT.Summer Generation by CountySummer Generation, MWChildress ----------Clay----------Coke----------Coleman----------Collin406406406406406406406406406406Colorado----------Comal6666666666Comanche----------Concho----------Cooke10101010101010101010Coryell----------Cottle----------Crane----------Crockett----------Crosby----------Culberson6666666666Dallas1,7261,7261,7261,7261,7261,7261,7261,7261,7261,726Dawson----------Delta----------Denton15404040404040404040Dewitt1111111111Dickens13131313131313131313Dimmit----------Duval----------Eastland5555555555Ector1,4851,4851,4851,4851,4851,4851,4851,4851,4851,485Edwards----------Ellis1,6261,6261,6261,6261,6261,6261,6261,6261,6261,626Erath----------Falls----------County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020These values are used in the summer import/export calculations for each county. Capacities for mothballed units are included asthe availablecapacity of the unit. Capacities for the wind units are at 8.7%. These values include the amount available for the grid according information from theowners of the private network units and the distributed generation units that have registered with ERCOT.Summer Generation by CountySummer Generation, MWFannin 1,5461,5461,5811,5931,6051,6171,6171,6171,6171,617Fayette1,8401,8401,8401,8401,8401,8401,8401,8401,8401,840Fisher----------Floyd5555555555Foard----------Fort Bend4,2424,2424,2424,2424,2424,2424,2424,2424,2424,242Franklin----------Freestone2,1532,1532,1532,1532,1532,1532,1532,1532,1532,153Frio278278278278278278278278278278Galveston967967967967967967967967967967Gillespie----------Glasscock19191919191919191919Goliad640640640640640640 1,3001,3001,3001,300Gonzales5555555555Grayson80808080808080808080Grimes1,0231,0231,0231,0231,0231,0231,3401,3401,3401,340Guadalupe1,7391,7391,7391,7391,7391,7391,7391,7391,7391,739Hall1111111111Hamilton----------Hardeman----------Harris6,4956,5686,5686,5687,9487,9487,9487,9487,9487,948Haskell----------Hays882882882882882882882882882882Henderson226226226226226226226226226226Hidalgo1,5851,5851,5851,5851,5851,5851,5851,5851,5851,585Hill----------Hood983983983983983983983983983983Hopkins----------Houston----------Howard296296307307307307307307307307County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020These values are used in the summer import/export calculations for each county. Capacities for mothballed units are included asthe availablecapacity of the unit. Capacities for the wind units are at 8.7%. These values include the amount available for the grid according information from theowners of the private network units and the distributed generation units that have registered with ERCOT.Summer Generation by CountySummer Generation, MWHunt 112112112112112112112112112112Irion----------Jack575 1,1541,1541,1541,1541,1541,1541,1541,1541,154Jackson----------Jeff Davis----------Jim Hogg----------Jim Wells----------Johnson269269269269269269269269269269Jones----------Karnes----------Kaufman1,8791,8791,8791,8791,8791,8791,8791,8791,8791,879Kendall----------Kenedy60606077777777777777Kent----------Kerr----------Kimble----------King----------Kinney----------Kleberg----------Knox----------La Salle----------Lamar1,3121,3121,3121,3121,3121,3121,3121,3121,3121,312Lampasas----------Lavaca----------Lee----------Leon----------Limestone1,6891,6891,6891,6891,6891,6891,6891,6891,6891,689Live Oak----------Llano492492492492492492492492492492Loving----------County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020These values are used in the summer import/export calculations for each county. Capacities for mothballed units are included asthe availablecapacity of the unit. Capacities for the wind units are at 8.7%. These values include the amount available for the grid according information from theowners of the private network units and the distributed generation units that have registered with ERCOT.Summer Generation by CountySummer Generation, MWMadison ----------Martin11111111111111111111Mason----------Matagorda2,7242,7242,7242,7242,7242,7242,7242,7242,7242,724Maverick24242424242424242424Mcculloch----------Mclennan-925925925925925925925925925Mcmullen----------Medina----------Menard----------Midland----------Milam1,1451,1451,1451,1451,1451,1451,1451,1451,1451,145Mills----------Mitchell420420420420420420420420420420Montague----------Montgomery5555555555Motley----------Nacogdoches-100100100100100100100100100Navarro----------Nolan134134134134134134134134134134Nueces2,0422,0422,0452,0452,0452,6653,2853,2853,2853,285Palo Pinto611611611611611611611611611611Parker1010--------Pecos61616161616161616161Presidio----------Rains----------Reagan----------Real----------Red River----------Reeves----------County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020These values are used in the summer import/export calculations for each county. Capacities for mothballed units are included asthe availablecapacity of the unit. Capacities for the wind units are at 8.7%. These values include the amount available for the grid according information from theowners of the private network units and the distributed generation units that have registered with ERCOT.Summer Generation by CountySummer Generation, MWRefugio ----------Robertson1,9281,9281,9281,9281,9281,9281,9281,9281,9281,928Rockwall----------Runnels----------Rusk3,2713,2713,2713,2713,2713,2713,2713,2713,2713,271San Patricio433433433433433433433433433433San Saba----------Schleicher----------Scurry64646464646464646464Shackelford49494949494949494949Smith----------Somervell2,4072,4072,4072,4072,4072,4072,4072,4072,4072,407Starr36363636363636363636Stephens----------Sterling71717171717171717171Stonewall----------Sutton----------Tarrant1,2671,2671,2671,2671,2671,2671,2671,2671,2671,267Taylor110110110110110110110110110110Terrell----------Throckmorton----------Titus1,8901,8901,8901,8901,8901,8901,8901,8901,8901,890Tom Green13131313131313131313Travis1,6261,6561,6561,6561,6561,6561,6561,6561,6561,656Upton31313131313131313131Uvalde----------Val Verde76767676767676767676Van Zandt----------Victoria521521521521521521521521521521Waller----------County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020These values are used in the summer import/export calculations for each county. Capacities for mothballed units are included asthe availablecapacity of the unit. Capacities for the wind units are at 8.7%. These values include the amount available for the grid according information from theowners of the private network units and the distributed generation units that have registered with ERCOT.Summer Generation by CountySummer Generation, MWWard 340340351356361367367367367367Washington----------Webb252252252252252252252252252252Wharton569569569569569569569569569569Wichita77777777777777777777Wilbarger760760760760760760760760760760Willacy-181818181818181818Williamson----------Wilson----------Winkler13131313131313131313Wise665665665665665665665665665665Wood----------Young615637637637637637637637637637Zapata----------Zavala----------Import: The county has less generation than load and must import generation.Export: The county has more generation than load and is able to export generation.County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020Anderson-135.0 -138.0 -141.4 -143.8 -146.0 -147.7 -150.2 -152.3 -154.4 -155.9Andrews-149.5 -152.9 -156.6 -159.3 -161.7 -163.6 -166.4 -168.7 -171.0 -172.7Angelina-192.9 -198.2 -204.1 -208.4 -212.2 -215.3 -219.7 -223.4 -227.0 -229.8Aransas-53.6 -54.8 -56.1 -57.1 -57.9 -58.6 -59.6 -60.5 -61.3 -61.9Archer-23.8 -24.4 -25.0 -25.4 -25.8 -26.1 -26.5 -26.9 -27.3 -27.5Atascosa311.3 309.5 307.5 306.1 304.8 303.8 302.3 301.1 299.9 298.9Austin-91.3 -93.3 -95.6 -97.2 -98.7 -99.8 -101.6 -102.9 -104.4 -105.4Bandera-56.6 -57.8 -59.2 -60.2 -61.1 -61.9 -62.9 -63.8 -64.7 -65.3Bastrop1482.5 1478.6 1474.3 1471.2 1468.4 1466.2 1462.9 1460.3 1457.6 1455.6Baylor-4.5 -4.6 -4.8 -4.8 -4.9 -5.0 -5.1 -5.1 -5.2 -5.2Bee-57.2 -58.5 -59.9 -60.9 -61.8 -62.6 -63.6 -64.5 -65.4 -66.1Bell-728.3 -744.6 -762.64.2 772.5 763.3 749.5 738.5 727.2 718.7Bexar531.1 436.8 332.3 256.2 188.4 134.7 55.0-9.0 -74.5 -123.6Blanco-28.3 -29.0 -29.7 -30.2 -30.6 -31.0 -31.5 -31.9 -32.4 -32.7Borden20.3 20.3 20.2 20.1 20.1 20.1 20.0 20.0 19.9 19.9Bosque761.1 760.0 758.7 757.7 756.9 756.2 755.3 754.5 753.7 753.1Brazoria-1571.7 -1615.8 -1664.5 -1700.1 -1731.7 -1756.8 -1794.0 -1823.9 -1854.4 -1877.4Brazos-325.2 -337.5 -351.2 -361.1 -370.0 -377.0 -387.4 -395.7 -404.3 -410.7Brewster-19.0 -19.4 -19.9 -20.2 -20.5 -20.7 -21.1 -21.4 -21.7 -21.9Brooks-18.8 -19.2 -19.7 -20.0 -20.3 -20.5 -20.9 -21.2 -21.5 -21.7Brown-114.4 -116.9 -119.8 -121.8 -123.7 -125.1 -127.3 -129.0 -130.8 -132.1Burleson-30.4 -31.1 -31.9 -32.4 -32.9 -33.3 -33.9 -34.3 -34.8 -35.2Burnet-21.6 -24.4 -27.4 -29.7 -31.7 -33.2 -35.6 -37.4 -39.3 -40.8Caldwell-103.4 -105.7 -108.3 -110.2 -111.8 -113.2 -115.1 -116.7 -118.3 -119.5Calhoun267.8 315.9 313.8 312.3 310.9 309.8 308.2 306.9 305.6 304.6SummerImport/Export,MWSummer Import/Export by CountyThis data is presented for example only. It is a calculation of the generation in the county less the projected coincident load in the county. Thetrue values will depend on actual load levels and actual generation dispatch.Import: The county has less generation than load and must import generation.Export: The county has more generation than load and is able to export generation.County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020SummerImport/Export,MWSummer Import/Export by CountyThis data is presented for example only. It is a calculation of the generation in the county less the projected coincident load in the county. Thetrue values will depend on actual load levels and actual generation dispatch.Callahan-31.7 -32.6 -33.6 -34.4 -35.1 -35.6 -36.4 -37.0 -37.6 -38.1Cameron-569.4 -584.7 -566.9 -579.3 -590.3 -599.0 -611.9 -622.3 -633.0 -640.9Chambers2217.3 2207.3 2196.1 2188.0 2180.8 2175.0 2166.5 2159.7 2152.7 2147.5Cherokee581.7 579.7 577.4 575.8 574.3 573.2 571.5 570.1 568.7 567.6Childress-14.8 -15.1 -15.5 -15.7 -16.0 -16.2 -16.4 -16.7 -16.9 -17.1Clay-24.8 -25.3 -25.9 -26.4 -26.8 -27.1 -27.6 -27.9 -28.3 -28.6Coke-21.2 -21.7 -22.2 -22.6 -22.9 -23.2 -23.6 -23.9 -24.2 -24.5Coleman-35.7 -36.5 -37.4 -38.0 -38.6 -39.1 -39.7 -40.3 -40.8 -41.2Collin-1873.5 -1924.4 -1980.9 -2022.0 -2058.6 -2087.6 -2130.6 -2165.2 -2200.5 -2227.1Colorado-80.0 -81.8 -83.8 -85.2 -86.5 -87.5 -89.0 -90.3 -91.5 -92.4Comal-341.3 -349.1 -357.7 -364.0 -369.5 -374.0 -380.5 -385.8 -391.2 -395.2Comanche-41.2 -42.1 -43.1 -43.9 -44.5 -45.0 -45.8 -46.4 -47.1 -47.6Concho-12.7 -13.0 -13.3 -13.5 -13.7 -13.9 -14.1 -14.3 -14.5 -14.7Cooke-115.9 -118.7 -121.8 -124.1 -126.1 -127.7 -130.1 -132.0 -134.0 -135.4Coryell-106.8 -109.2 -111.8 -113.8 -115.5 -116.8 -118.9 -120.5 -122.1 -123.4Cottle-4.0 -4.1 -4.2 -4.3 -4.3 -4.4 -4.4 -4.5 -4.6 -4.6Crane-82.9 -84.7 -86.8 -88.3 -89.6 -90.6 -92.2 -93.5 -94.7 -95.7Crockett-39.4 -40.2 -41.2 -41.9 -42.6 -43.1 -43.8 -44.4 -45.0 -45.5Crosby-1.8 -1.8 -1.9 -1.9 -1.9 -2.0 -2.0 -2.0 -2.1 -2.1Culberson0.9 0.8 0.7 0.6 0.5 0.4 0.3 0.3 0.2 0.1Dallas-5955.7 -6127.4 -6317.5 -6456.0 -6579.4 -6677.1 -6822.0 -6938.6 -7057.7 -7147.1Dawson-67.3 -68.8 -70.5 -71.7 -72.8 -73.7 -74.9 -76.0 -77.0 -77.8Delta-11.6 -11.9 -12.2 -12.4 -12.6 -12.7 -12.9 -13.1 -13.3 -13.4Denton-2078.6 -2100.3 -2152.1 -2189.9 -2223.5 -2250.2 -2289.6 -2321.4 -2353.9 -2378.2Dewitt-69.8 -71.3 -73.1 -74.4 -75.5 -76.4 -77.7 -78.8 -79.9 -80.7Dickens5.5 5.4 5.2 5.0 4.9 4.8 4.7 4.6 4.4 4.4Import: The county has less generation than load and must import generation.Export: The county has more generation than load and is able to export generation.County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020SummerImport/Export,MWSummer Import/Export by CountyThis data is presented for example only. It is a calculation of the generation in the county less the projected coincident load in the county. Thetrue values will depend on actual load levels and actual generation dispatch.Dimmit-17.6 -18.0 -18.4 -18.8 -19.0 -19.3 -19.6 -19.9 -20.1 -20.3Duval-46.7 -47.7 -48.9 -49.7 -50.5 -51.1 -52.0 -52.7 -53.4 -53.9Eastland-52.8 -54.1 -55.5 -56.6 -57.5 -58.2 -59.3 -60.2 -61.1 -61.8Ector1062.1 1052.6 1042.1 1034.5 1027.7 1022.3 1014.4 1007.9 1001.4 996.5Edwards-8.8 -9.0 -9.2 -9.3 -9.5 -9.6 -9.7 -9.9 -10.0 -10.1Ellis1044.0 1031.0 1016.6 1006.1 996.7 989.3 978.3 969.5 960.5 953.7Erath-105.2 -107.5 -110.1 -112.0 -113.7 -115.0 -117.0 -118.6 -120.2 -121.5Falls-46.7 -47.7 -48.9 -49.7 -50.5 -51.1 -52.0 -52.7 -53.4 -54.0Fannin1474.1 1472.5 1506.1 1516.7 1527.5 1538.5 1537.1 1536.0 1534.9 1534.1Fayette1761.7 1759.9 1758.0 1756.6 1755.3 1754.3 1752.8 1751.7 1750.4 1749.5Fisher-23.6 -24.1 -24.7 -25.1 -25.5 -25.8 -26.2 -26.6 -27.0 -27.2Floyd5.2 5.2 5.2 5.2 5.2 5.2 5.2 5.2 5.2 5.2Foard-3.2 -3.2 -3.3 -3.4 -3.4 -3.5 -3.5 -3.6 -3.6 -3.6Fort Bend2973.1 2944.7 2913.3 2890.5 2870.1 2853.9 2830.0 2810.8 2791.1 2776.3Franklin-3.0 -3.1 -3.1 -3.2 -3.2 -3.3 -3.3 -3.4 -3.4 -3.5Freestone2099.1 2097.9 2096.5 2095.6 2094.7 2094.0 2093.0 2092.2 2091.4 2090.7Frio244.4 243.7 242.9 242.3 241.8 241.3 240.7 240.2 239.7 239.3Galveston-413.8 -444.7 -478.8 -503.7 -525.9 -543.5 -569.5 -590.5 -611.9 -628.0Gillespie-66.1 -67.6 -69.2 -70.4 -71.5 -72.3 -73.6 -74.6 -75.6 -76.4Glasscock-0.6 -1.1 -1.5 -1.9 -2.2 -2.4 -2.8 -3.1 -3.4 -3.6Goliad618.8 618.3 617.8 617.4 617.0 616.8 1276.4 1276.1 1275.7 1275.5Gonzales-54.6 -56.0 -57.4 -58.5 -59.5 -60.2 -61.3 -62.2 -63.2 -63.9Grayson-365.4 -375.4 -386.4 -394.4 -401.6 -407.3 -415.7 -422.4 -429.3 -434.5Grimes1003.2 1002.7 1002.2 1001.9 1001.6 1001.3 1317.9 1317.6 1317.3 1317.1Guadalupe1486.1 1480.4 1474.2 1469.6 1465.6 1462.3 1457.6 1453.7 1449.8 1446.9Hall-4.1 -4.2 -4.3 -4.4 -4.5 -4.6 -4.7 -4.7 -4.8 -4.9Import: The county has less generation than load and must import generation.Export: The county has more generation than load and is able to export generation.County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020SummerImport/Export,MWSummer Import/Export by CountyThis data is presented for example only. It is a calculation of the generation in the county less the projected coincident load in the county. Thetrue values will depend on actual load levels and actual generation dispatch.Hamilton-21.3 -21.8 -22.3 -22.7 -23.1 -23.3 -23.8 -24.1 -24.4 -24.7Hardeman-16.2 -16.6 -17.0 -17.2 -17.5 -17.7 -18.0 -18.3 -18.5 -18.7Harris-6206.9 -6417.6 -6732.0 -6961.0 -5785.0 -5946.7 -6186.3 -6379.0 -6575.9 -6723.8Haskell-26.1 -26.7 -27.3 -27.8 -28.2 -28.6 -29.1 -29.5 -29.9 -30.2Hays450.7 441.1 430.4 422.6 415.7 410.2 402.1 395.5 388.8 383.8Henderson65.4 61.8 57.8 54.9 52.3 50.3 47.3 44.8 42.3 40.5Hidalgo371.1 344.0 313.9 292.1 272.6 257.1 234.2 215.8 197.0 182.9Hill-97.9 -100.1 -102.5 -104.3 -105.9 -107.1 -109.0 -110.4 -112.0 -113.1Hood758.9 753.9 748.3 744.3 740.7 737.9 733.6 730.2 726.8 724.1Hopkins-111.9 -114.4 -117.2 -119.2 -121.0 -122.4 -124.5 -126.2 -127.9 -129.2Houston-39.7 -40.6 -41.5 -42.3 -42.9 -43.4 -44.1 -44.7 -45.4 -45.8Howard182.0 179.5 187.2 185.1 183.3 181.8 179.7 178.0 176.2 174.9Hunt-130.0 -135.5 -141.4 -145.8 -149.7 -152.8 -157.4 -161.0 -164.8 -167.6Irion-10.6 -10.8 -11.1 -11.3 -11.5 -11.6 -11.8 -12.0 -12.1 -12.3Jack553.0 1131.5 1130.9 1130.5 1130.2 1129.9 1129.5 1129.1 1128.8 1128.6Jackson-36.6 -37.4 -38.3 -39.0 -39.6 -40.1 -40.7 -41.3 -41.9 -42.3Jeff Davis-3.9 -3.9 -4.0 -4.1 -4.2 -4.2 -4.3 -4.3 -4.4 -4.4Jim Hogg-3.1 -3.2 -3.3 -3.4 -3.4 -3.4 -3.5 -3.5 -3.6 -3.6Jim Wells-83.9 -85.8 -87.9 -89.4 -90.7 -91.8 -93.4 -94.6 -95.9 -96.9Johnson-75.4 -83.1 -91.6 -97.8 -103.4 -107.8 -114.3 -119.5 -124.8 -128.8Jones-45.2 -46.2 -47.3 -48.1 -48.8 -49.4 -50.3 -51.0 -51.7 -52.2Karnes-28.4 -29.0 -29.7 -30.2 -30.7 -31.0 -31.6 -32.0 -32.4 -32.8Kaufman1595.0 1588.7 1581.6 1576.5 1571.9 1568.3 1563.0 1558.7 1554.3 1550.9Kendall-102.1 -104.4 -106.9 -108.8 -110.4 -111.7 -113.7 -115.2 -116.8 -118.0Kenedy58.3 58.3 58.3 75.8 75.8 75.8 75.8 75.8 75.7 75.7Kent-54.4 -55.6 -57.0 -57.9 -58.8 -59.5 -60.5 -61.4 -62.2 -62.8Import: The county has less generation than load and must import generation.Export: The county has more generation than load and is able to export generation.County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020SummerImport/Export,MWSummer Import/Export by CountyThis data is presented for example only. It is a calculation of the generation in the county less the projected coincident load in the county. Thetrue values will depend on actual load levels and actual generation dispatch.Kerr-133.1 -136.1 -139.4 -141.8 -143.9 -145.6 -148.1 -150.1 -152.2 -153.7Kimble-14.7 -15.1 -15.4 -15.7 -15.9 -16.1 -16.4 -16.6 -16.9 -17.0King-7.6 -7.8 -8.0 -8.1 -8.2 -8.3 -8.5 -8.6 -8.7 -8.8Kinney-5.7 -5.8 -6.0 -6.1 -6.1 -6.2 -6.3 -6.4 -6.5 -6.6Kleberg-75.2 -76.9 -78.8 -80.1 -81.3 -82.3 -83.7 -84.9 -86.0 -86.9Knox-20.9 -21.4 -21.9 -22.3 -22.6 -22.9 -23.3 -23.6 -23.9 -24.2La Salle-14.5 -14.8 -15.2 -15.5 -15.7 -15.9 -16.2 -16.4 -16.6 -16.8Lamar1157.0 1153.5 1149.7 1146.9 1144.4 1142.5 1139.5 1137.2 1134.8 1133.0Lampasas-51.9 -53.1 -54.4 -55.3 -56.1 -56.8 -57.8 -58.5 -59.4 -60.0Lavaca-38.2 -39.0 -40.0 -40.7 -41.3 -41.8 -42.5 -43.1 -43.6 -44.1Lee-35.6 -36.4 -37.3 -38.0 -38.5 -39.0 -39.6 -40.2 -40.7 -41.2Leon-62.2 -63.6 -65.1 -66.2 -67.2 -68.0 -69.2 -70.1 -71.1 -71.8Limestone1622.9 1621.4 1619.8 1618.6 1617.5 1616.7 1615.5 1614.5 1613.4 1612.7Live Oak-75.8 -77.5 -79.4 -80.8 -82.0 -83.0 -84.4 -85.5 -86.7 -87.6Llano423.0 421.4 419.7 418.5 417.3 416.5 415.2 414.1 413.1 412.2Loving-7.9 -8.1 -8.3 -8.5 -8.6 -8.7 -8.8 -9.0 -9.1 -9.2Madison-4.4 -4.5 -4.6 -4.7 -4.7 -4.8 -4.9 -4.9 -5.0 -5.1Martin-19.4 -20.0 -20.8 -21.3 -21.8 -22.2 -22.8 -23.2 -23.7 -24.0Mason-12.1 -12.4 -12.7 -12.9 -13.1 -13.2 -13.5 -13.6 -13.8 -14.0Matagorda2582.9 2579.7 2576.2 2573.7 2571.4 2569.6 2567.0 2564.8 2562.7 2561.0Maverick-60.2 -62.0 -64.1 -65.6 -67.0 -68.1 -69.6 -70.9 -72.2 -73.2Mcculloch-29.5 -30.1 -30.9 -31.4 -31.9 -32.2 -32.8 -33.2 -33.7 -34.0Mclennan-720.4188.5 170.7 157.7 146.1 137.0 123.4 112.5 101.3 92.9Mcmullen-7.9 -8.1 -8.3 -8.5 -8.6 -8.7 -8.8 -9.0 -9.1 -9.2Medina-200.8 -205.3 -210.3 -213.9 -217.2 -219.7 -223.5 -226.5 -229.7 -232.0Menard-5.9 -6.0 -6.1 -6.3 -6.3 -6.4 -6.5 -6.6 -6.7 -6.8Import: The county has less generation than load and must import generation.Export: The county has more generation than load and is able to export generation.County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020SummerImport/Export,MWSummer Import/Export by CountyThis data is presented for example only. It is a calculation of the generation in the county less the projected coincident load in the county. Thetrue values will depend on actual load levels and actual generation dispatch.Midland-362.7 -370.8 -379.7 -386.3 -392.1 -396.7 -403.6 -409.1 -414.7 -418.9Milam1077.7 1076.2 1074.5 1073.3 1072.2 1071.4 1070.1 1069.1 1068.0 1067.3Mills-9.2 -9.4 -9.7 -9.8 -10.0 -10.1 -10.3 -10.4 -10.6 -10.7Mitchell398.6 398.1 397.6 397.2 396.9 396.6 396.2 395.9 395.5 395.3Montague-65.7 -67.2 -68.8 -70.0 -71.0 -71.9 -73.1 -74.1 -75.1 -75.9Montgomery-224.6 -229.7 -235.4 -239.5 -243.2 -246.1 -250.5 -253.9 -257.5 -260.2Motley-3.7 -3.8 -3.9 -4.0 -4.0 -4.1 -4.2 -4.2 -4.3 -4.3Nacogdoches-163.8 -67.5 -71.5 -74.5 -77.1 -79.2 -82.3 -84.8 -87.3 -89.2Navarro-187.8 -191.9 -196.6 -200.0 -203.0 -205.4 -208.9 -211.8 -214.7 -216.9Nolan78.0 76.7 75.4 74.3 73.4 72.7 71.7 70.8 70.0 69.3Nueces1046.7 1024.5 1002.9 984.9 968.9 1576.3 2177.5 2162.4 2147.0 2135.4Palo Pinto526.0 524.1 522.0 520.4 519.1 518.0 516.4 515.1 513.8 512.8Parker-330.0 -337.6 -355.5 -361.6 -367.1 -371.4 -377.8 -383.0 -388.2 -392.2Pecos-31.4 -33.5 -35.8 -37.4 -38.9 -40.1 -41.9 -43.3 -44.7 -45.8Presidio-10.6 -10.8 -11.1 -11.3 -11.4 -11.6 -11.8 -11.9 -12.1 -12.2Rains-25.8 -26.4 -27.0 -27.5 -27.9 -28.2 -28.7 -29.1 -29.5 -29.8Reagan-16.1 -16.5 -16.9 -17.2 -17.4 -17.6 -17.9 -18.2 -18.4 -18.6Real-10.6 -10.8 -11.1 -11.3 -11.4 -11.6 -11.8 -11.9 -12.1 -12.2Red River-24.8 -25.4 -26.0 -26.4 -26.8 -27.1 -27.6 -28.0 -28.4 -28.7Reeves-35.3 -36.1 -37.0 -37.6 -38.2 -38.6 -39.3 -39.8 -40.4 -40.8Refugio-22.6 -23.1 -23.6 -24.0 -24.4 -24.7 -25.1 -25.5 -25.8 -26.1Robertson1895.7 1895.0 1894.2 1893.6 1893.1 1892.7 1892.1 1891.6 1891.1 1890.7Rockwall-256.3 -262.0 -268.4 -273.0 -277.1 -280.4 -285.2 -289.1 -293.1 -296.0Runnels-32.0 -32.7 -33.5 -34.1 -34.6 -35.0 -35.6 -36.1 -36.6 -36.9Rusk3263.9 3263.8 3263.6 3263.5 3263.4 3263.3 3263.1 3263.0 3262.9 3262.8San Patricio293.7 290.6 287.1 284.6 282.4 280.6 278.0 275.8 273.7 272.1Import: The county has less generation than load and must import generation.Export: The county has more generation than load and is able to export generation.County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020SummerImport/Export,MWSummer Import/Export by CountyThis data is presented for example only. It is a calculation of the generation in the county less the projected coincident load in the county. Thetrue values will depend on actual load levels and actual generation dispatch.San Saba-12.6 -12.9 -13.2 -13.4 -13.6 -13.8 -14.0 -14.2 -14.4 -14.5Schleicher-13.9 -14.2 -14.5 -14.8 -15.0 -15.2 -15.5 -15.7 -15.9 -16.0Scurry-47.7 -50.2 -53.0 -55.0 -56.7 -58.2 -60.3 -62.0 -63.7 -65.0Shackelford35.4 35.1 34.8 34.5 34.3 34.1 33.9 33.7 33.4 33.3Smith-600.8 -614.2 -629.1 -639.9 -649.6 -657.2 -668.6 -677.7 -687.0 -694.0Somervell2379.4 2378.8 2378.1 2377.6 2377.2 2376.8 2376.3 2375.9 2375.5 2375.1Starr-32.3 -33.8 -35.5 -36.8 -37.9 -38.7 -40.0 -41.1 -42.1 -42.9Stephens-67.2 -68.7 -70.4 -71.6 -72.7 -73.5 -74.8 -75.8 -76.9 -77.7Sterling58.8 58.5 58.2 58.0 57.8 57.7 57.5 57.3 57.1 56.9Stonewall-6.1 -6.3 -6.4 -6.5 -6.6 -6.7 -6.8 -6.9 -7.0 -7.1Sutton-17.8 -18.2 -18.7 -19.0 -19.3 -19.5 -19.8 -20.1 -20.4 -20.6Tarrant-4061.4 -4180.5 -4312.3 -4408.4 -4494.0 -4561.8 -4662.3 -4743.2 -4825.7 -4887.8Taylor-253.0 -261.1 -270.0 -276.6 -282.4 -287.0 -293.8 -299.3 -305.0 -309.2Terrell-1.9 -1.9 -2.0 -2.0 -2.0 -2.1 -2.1 -2.1 -2.2 -2.2Throckmorton-7.9 -8.0 -8.2 -8.4 -8.5 -8.6 -8.7 -8.9 -9.0 -9.1Titus1890.0 1890.0 1890.0 1890.0 1890.0 1890.0 1890.0 1890.0 1890.0 1890.0Tom Green-256.5 -262.5 -269.2 -274.1 -278.4 -281.8 -286.9 -291.0 -295.2 -298.3Travis-920.7 -947.6 -1010.6 -1056.5 -1097.5 -1129.9 -1177.9 -1216.6 -1256.1 -1285.7Upton7.3 6.8 6.2 5.8 5.4 5.1 4.6 4.3 3.9 3.6Uvalde-54.3 -55.5 -56.8 -57.8 -58.7 -59.4 -60.4 -61.2 -62.1 -62.7Val Verde-14.6 -16.6 -18.8 -20.5 -21.9 -23.1 -24.8 -26.1 -27.5 -28.6Van Zandt-64.1 -65.6 -67.2 -68.3 -69.3 -70.2 -71.4 -72.3 -73.3 -74.1Victoria260.3 254.5 248.0 243.3 239.2 235.8 230.9 227.0 222.9 219.9Waller-197.7 -202.1 -207.0 -210.6 -213.7 -216.3 -220.0 -223.0 -226.1 -228.4Ward269.8 268.2 277.2 281.3 285.5 290.0 288.6 287.6 286.5 285.7Washington-116.8 -119.4 -122.3 -124.4 -126.3 -127.8 -130.0 -131.8 -133.6 -135.0Import: The county has less generation than load and must import generation.Export: The county has more generation than load and is able to export generation.County2011 2012 2013 2014 2015 2016 2017 2018 2019 2020SummerImport/Export,MWSummer Import/Export by CountyThis data is presented for example only. It is a calculation of the generation in the county less the projected coincident load in the county. Thetrue values will depend on actual load levels and actual generation dispatch.Webb-177.6 -187.2 -197.8 -205.5 -212.4 -217.9 -226.0 -232.5 -239.2 -244.2Wharton456.7 454.2 451.4 449.4 447.6 446.1 444.0 442.3 440.6 439.3Wichita-333.4 -342.5 -352.7 -360.1 -366.7 -371.9 -379.7 -385.9 -392.2 -397.0Wilbarger723.9 723.0 722.2 721.5 720.9 720.5 719.8 719.2 718.7 718.3Willacy-36.9 -20.1 -21.0 -21.7 -22.3 -22.8 -23.5 -24.0 -24.6 -25.0Williamson-1064.4 -1088.2 -1114.6 -1133.8 -1150.8 -1164.4 -1184.5 -1200.6 -1217.1 -1229.5Wilson-74.4 -76.1 -77.9 -79.3 -80.5 -81.4 -82.8 -83.9 -85.1 -86.0Winkler-32.4 -33.4 -34.6 -35.4 -36.1 -36.7 -37.6 -38.3 -39.0 -39.5Wise456.3 451.6 446.4 442.7 439.3 436.7 432.7 429.5 426.3 423.9Wood-7.4 -7.6 -7.8 -7.9 -8.0 -8.1 -8.3 -8.4 -8.5 -8.6Young554.2 574.6 573.1 572.0 571.0 570.2 569.1 568.2 567.2 566.5Zapata-27.3 -27.9 -28.6 -29.1 -29.5 -29.9 -30.4 -30.8 -31.2 -31.5County2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Anderson154157160162164167 170 171 173 175Andrews123125127129131133 135 137 138 140Angelina203206209212215219 222 225 227 230Aransas596061626263 64 65 66 67Archer222323232424 24 25 25 25Atascosa777879808183 84 85 86 87Austin838486878890 91 92 93 94Bandera656668696971 72 72 73 74Bastrop163165168171173176 179 180 182 185Baylor444444 5 5 5 5Bee505152535354 55 56 56 57Bell746758770782791806 818 826 834 846Bexar2,7832,8292,8752,9182,9533,007 3,0553,084 3,113 3,158Blanco333434353536 36 37 37 37Borden222222 2 2 2 2Bosque434444454546 47 47 48 49Brazoria1,6481,6751,7021,7281,7491,781 1,8091,826 1,844 1,870Brazos374380386392396404 410 414 418 424Brewster191920202021 21 21 21 22Brooks171718181818 19 19 19 19Brown969799100102103 105 106 107 109Burleson292930303131 32 32 32 33Burnet121123125127128131 133 134 135 137Caldwell959798100101103 104 105 106 108Calhoun737475767778 80 80 81 82Callahan363738383939 40 40 41 41Cameron634645655665673685 696 703 710 720Winter Load, MWThe loads shown are the projected coincident loads of the individual delivery points from the 2011 ALDRs and do not include self-serve loads.The ALDR values were used to compute a percentage of load by county, and the percentage was applied to the forecasted ERCOT coincidentpeak. The values shown here are used in the Winter import/export calculations.Winter Load by CountyCounty2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Winter Load, MWThe loads shown are the projected coincident loads of the individual delivery points from the 2011 ALDRs and do not include self-serve loads.The ALDR values were used to compute a percentage of load by county, and the percentage was applied to the forecasted ERCOT coincidentpeak. The values shown here are used in the Winter import/export calculations.Winter Load by CountyChambers370376382388393400 406 410 414 420Cherokee707172737476 77 78 78 79Childress101010101011 11 11 11 11Clay212222222223 23 23 24 24Coke141414151515 15 15 16 16Coleman303031313132 32 33 33 34Collin1,4101,4331,4561,4781,4961,524 1,5481,562 1,577 1,600Colorado686970717274 75 75 76 77Comal327333338343347354 359 363 366 371Comanche363637383839 39 40 40 41Concho777777 7 7 7 8Cooke113115117118120122 124 125 126 128Coryell99100102104105107 108 109 110 112Cottle333333 3 3 3 3Crane737476777879 80 81 82 83Crockett303031313232 33 33 33 34Crosby222222 2 2 2 2Culberson333333 3 3 3 3Dallas5,3655,4535,5425,6255,6935,7975,8905,945 6,002 6,088Dawson323233333434 35 35 35 36Delta9910101010 10 10 10 11Denton1,3131,3351,3561,3771,3931,419 1,4421,455 1,469 1,490Dewitt596061626364 65 66 66 67Dickens666777 7 7 7 7Dimmit111111111212 12 12 12 12Duval474849495051 52 52 53 53Eastland505051525354 54 55 55 56Ector298303308312316322 327330 333 338County2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Winter Load, MWThe loads shown are the projected coincident loads of the individual delivery points from the 2011 ALDRs and do not include self-serve loads.The ALDR values were used to compute a percentage of load by county, and the percentage was applied to the forecasted ERCOT coincidentpeak. The values shown here are used in the Winter import/export calculations.Winter Load by CountyEdwards99991010 10 10 10 10Ellis676687698708717730 742 749 756 767Erath94959798100102 103 104 105 107Falls394041414243 43 44 44 45Fannin596061626364 65 66 67 67Fayette697071727374 75 76 77 78Fisher242425252526 26 27 27 27Floyd------ - - - -Foard233333 3 3 3 3Fort Bend620630640650658670 680 687 693 703Franklin223333 3 3 3 3Freestone505051525354 54 55 55 56Frio232324242425 25 25 25 26Galveston1,0661,0831,1011,1181,1311,152 1,1701,181 1,192 1,209Gillespie616263646466 67 67 68 69Glasscock131314141414 14 15 15 15Goliad242424252525 26 26 26 27Gonzales505152535354 55 56 56 57Grayson369375381387391398405 408 412 418Grimes232324242425 25 25 26 26Guadalupe275279284288292297 302 305 308 312Hall222222 2 2 2 2Hamilton161617171717 18 18 18 18Hardeman111111111112 12 12 12 12Harris8,8068,9509,0969,2339,3449,515 9,6679,757 9,851 9,992Haskell151616161617 17 17 17 18Hays344349355360365371 377 381 385 390Henderson161163166168170174 176178 180 182County2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Winter Load, MWThe loads shown are the projected coincident loads of the individual delivery points from the 2011 ALDRs and do not include self-serve loads.The ALDR values were used to compute a percentage of load by county, and the percentage was applied to the forecasted ERCOT coincidentpeak. The values shown here are used in the Winter import/export calculations.Winter Load by CountyHidalgo1,0801,0971,1151,1321,1451,166 1,1851,196 1,208 1,225Hill899092939496 98 98 99 101Hood194198201204206210 213 215 217 221Hopkins9698100101102104 106 107 108 109Houston272728282929 30 30 30 31Howard757677787981 82 83 84 85Hunt216220223227229234 237 240 242 245Irion101010101011 11 11 11 11Jack181818191919 20 20 20 20Jackson343535363637 37 38 38 39Jeff Davis566666 6 6 6 6Jim Hogg334444 4 4 4 4Jim Wells848687888991 92 93 94 96Johnson345351357362366373 379 383 386 392Jones394041414243 43 44 44 45Karnes242525262626 27 27 27 28Kaufman317322327332336343 348 351 355 360Kendall105107108110111113 115 116 117 119Kenedy1111122 2 2 2Kent464748494950 51 52 52 53Kerr140142145147149151 154 155 157 159Kimble151616161617 17 17 17 18King777778 8 8 8 8Kinney556666 6 6 6 6Kleberg525354555657 57 58 59 59Knox101010101010 11 11 11 11La Salle141515151515 16 16 16 16Lamar127129131133135138 140141 142 144County2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Winter Load, MWThe loads shown are the projected coincident loads of the individual delivery points from the 2011 ALDRs and do not include self-serve loads.The ALDR values were used to compute a percentage of load by county, and the percentage was applied to the forecasted ERCOT coincidentpeak. The values shown here are used in the Winter import/export calculations.Winter Load by CountyLampasas505152535354 55 56 56 57Lavaca303031313232 33 33 33 34Lee303031313232 33 33 34 34Leon535455555657 58 59 59 60Limestone596061626364 65 66 66 67Live Oak626364656667 68 69 70 71Llano767879808183 84 85 86 87Loving566666 6 6 6 6Madison566666 6 6 6 6Martin202020212121 22 22 22 22Mason111111111212 12 12 12 12Matagorda119121123125127129 131 132 133 135Maverick777980818284 85 86 87 88Mcculloch212122222223 23 23 23 24Mclennan580590600609616627 637 643 649 659Mcmullen888888 9 9 9 9Medina157160162165167170 173 174 176 178Menard777777 7 7 8 8Midland221224228231234238242 245 247 250Milam596061626264 65 65 66 67Mills888888 9 9 9 9Mitchell171717171818 18 18 19 19Montague535455565758 58 59 60 60Montgomery173176179182184187 190 192 194 197Motley333344 4 4 4 4Nacogdoches130132134136138140 142 144 145 147Navarro151154156159160163 166 168 169 172Nolan444545464748 4849 49 50County2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Winter Load, MWThe loads shown are the projected coincident loads of the individual delivery points from the 2011 ALDRs and do not include self-serve loads.The ALDR values were used to compute a percentage of load by county, and the percentage was applied to the forecasted ERCOT coincidentpeak. The values shown here are used in the Winter import/export calculations.Winter Load by CountyNueces832846860873883899 914 922 931 944Palo Pinto697071737375 76 77 77 79Parker360366372378382389 396 399 403 409Pecos686970717274 75 76 76 77Presidio111111111112 12 12 12 12Rains181919191920 20 20 21 21Reagan151515161616 16 17 17 17Real121212131313 13 13 13 14Red River222222232323 24 24 24 24Reeves171718181819 19 19 19 19Refugio222222232323 24 24 24 25Robertson242525262626 27 27 27 28Rockwall243247251255258263 267 270 272 276Runnels262626272728 28 28 29 29Rusk555555 5 5 5 5San Patricio149152154156158161 164 165 167 169San Saba111111111212 12 12 12 12Schleicher111111111112 12 12 12 12Scurry87899092939496 97 98 99Shackelford111111111112 12 12 12 12Smith444451459465471480 487 492 497 504Somervell272727282829 29 29 30 30Starr636465666768 69 70 71 72Stephens555556575859 60 60 61 62Sterling666666 6 6 6 6Stonewall777777 7 7 7 8Sutton161617171717 18 18 18 18Tarrant4,0574,1244,1914,2544,3054,384 4,4544,4954,539 4,604County2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Winter Load, MWThe loads shown are the projected coincident loads of the individual delivery points from the 2011 ALDRs and do not include self-serve loads.The ALDR values were used to compute a percentage of load by county, and the percentage was applied to the forecasted ERCOT coincidentpeak. The values shown here are used in the Winter import/export calculations.Winter Load by CountyTaylor252256260264267272 276 279 282 286Terrell222222 2 2 2 2Throckmorton777777 8 8 8 8Titus------ - - - -Tom Green190193196199202205 209 211 213 216Travis1,5261,5511,5761,6001,6191,648 1,6751,690 1,707 1,731Upton141414141515 15 15 15 16Uvalde474748495050 51 52 52 53Val Verde767879808183 84 85 85 87Van Zandt636465666668 69 69 70 71Victoria203207210213216220 223 225 227 231Waller152154157159161164 167 168 170 172Ward484950505152 53 53 54 55Washington94969899100102 104 105 106 107Webb343349355360364371 377 380 384 390Wharton100102104105106108 110 111 112 114Wichita271275280284287293 297 300 303 307Wilbarger222222232323 24 24 24 25Willacy30313132323233 33 34 34Williamson710722733744753767 779 787 794 806Wilson666768697071 72 73 73 74Winkler414142434344 45 45 45 46Wise212215219222225229 233 235 237 240Young444545464747 48 49 49 50Zapata272728282829 29 30 30 30Zavala181919192020 20 20 21 21County2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Anderson------ - - - -Andrews------ - - - -Angelina484848484848 48 48 48 48Aransas------ - - - -Archer------ - - - -Atascosa395395395395395395 395 395 395 395Austin------ - - - -Bandera------ - - - -Bastrop1,7421,7421,7421,7421,7421,742 1,742 1,742 1,742 1,742Baylor------ - - - -Bee------ - - - -Bell---780 1,5601,560 1,560 1,560 1,560 1,560Bexar4,8904,8904,8904,8904,8904,890 4,890 4,890 4,890 4,890Blanco------ - - - -Borden232323232323 23 23 23 23Bosque869869869869869869 869 869 869 869Brazoria411411411411411411 411 411 411411Brazos226226226226226226 226 226 226 226Brewster------ - - - -Brooks------ - - - -Brown------ - - - -Burleson------ - - - -Burnet102102102102102102 102 102 102 102Caldwell------ - - - -Calhoun376406406406406406 406 406 406 406Callahan101010101010 10 10 10 10Cameron128128163163163163 163 163 163 163Winter Generation by CountyThese values are used in the summer import/export calculations for each county. Capacities for mothballed units are included asthe availablecapacity of the unit. Capacities for the wind units are at 8.7%. These values include the amount available for the grid according informationfrom the owners of the private network units and the distributed generation units that have registered with ERCOT.Winter Generation, MWCounty2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Winter Generation by CountyThese values are used in the summer import/export calculations for each county. Capacities for mothballed units are included asthe availablecapacity of the unit. Capacities for the wind units are at 8.7%. These values include the amount available for the grid according informationfrom the owners of the private network units and the distributed generation units that have registered with ERCOT.Winter Generation, MWChambers2,2982,2982,2982,2982,2982,298 2,298 2,298 2,298 2,298Cherokee673673673673673673 673 673 673 673Childress------ - - - -Clay------ - - - -Coke------ - - - -Coleman------ - - - -Collin415415415415415415 415 415 415 415Colorado------ - - - -Comal666666 6 6 6 6Comanche------ - - - -Concho------ - - - -Cooke101010101010 10 10 10 10Coryell------ - - - -Cottle------ - - - -Crane------ - - - -Crockett------ - - - -Crosby------ - - - -Culberson666666 6 6 6 6Dallas1,7341,7341,7341,7341,7341,734 1,734 1,734 1,734 1,734Dawson------ - - - -Delta------ - - - -Denton404040404040 40 40 40 40Dewitt111111 1 1 1 1Dickens131313131313 13 13 13 13Dimmit------ - - --Duval------ - - - -Eastland555555 5 5 5 5Ector1,6061,6061,6061,6061,6061,606 1,606 1,606 1,606 1,606County2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Winter Generation by CountyThese values are used in the summer import/export calculations for each county. Capacities for mothballed units are included asthe availablecapacity of the unit. Capacities for the wind units are at 8.7%. These values include the amount available for the grid according informationfrom the owners of the private network units and the distributed generation units that have registered with ERCOT.Winter Generation, MWEdwards------ - - - -Ellis1,8001,8001,8001,8001,8001,800 1,800 1,800 1,800 1,800Erath------ - - - -Falls------ - - - -Fannin1,6301,6301,6301,6301,6301,630 1,630 1,630 1,630 1,630Fayette1,8531,8531,8531,8531,8531,853 1,853 1,853 1,853 1,853Fisher------ - - - -Floyd555555 5 5 5 5Foard------ - - - -Fort Bend4,2734,2734,2734,2734,2734,273 4,273 4,273 4,273 4,273Franklin------ - - - -Freestone2,2482,2482,2482,2482,2482,248 2,248 2,248 2,248 2,248Frio278278278278278278 278 278 278 278Galveston1,1341,1341,1341,1341,1341,134 1,134 1,134 1,134 1,134Gillespie------ - - - -Glasscock191919191919 19 19 19 19Goliad640640640640640640 1,300 1,300 1,300 1,300Gonzales555555 5 5 5 5Grayson808080808080 80 80 80 80Grimes1,0831,0831,0831,0831,0831,083 1,400 1,400 1,400 1,400Guadalupe1,8841,8841,8841,8841,8841,884 1,884 1,884 1,884 1,884Hall111111 1 1 1 1Hamilton------ - - - -Hardeman------ - - - -Harris7,1617,1597,1597,1598,5398,539 8,539 8,539 8,5398,539Haskell------ - - - -Hays968968968968968968 968 968 968 968Henderson226226226226226226 226 226 226 226County2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Winter Generation by CountyThese values are used in the summer import/export calculations for each county. Capacities for mothballed units are included asthe availablecapacity of the unit. Capacities for the wind units are at 8.7%. These values include the amount available for the grid according informationfrom the owners of the private network units and the distributed generation units that have registered with ERCOT.Winter Generation, MWHidalgo1,8261,8261,8261,8261,8261,826 1,826 1,826 1,826 1,826Hill------ - - - -Hood1,1051,1051,1051,1051,1051,105 1,105 1,105 1,105 1,105Hopkins------ - - - -Houston------ - - - -Howard296296307307307307 307 307 307 307Hunt112112112112112112 112 112 112 112Irion------ - - - -Jack1,2351,2491,2491,2491,2491,249 1,249 1,249 1,249 1,249Jackson------ - - - -Jeff Davis------ - - - -Jim Hogg------ - - - -Jim Wells------ - - - -Johnson283283283283283283 283 283 283 283Jones------ - - - -Karnes------ - - - -Kaufman1,9391,9391,9391,9391,9391,939 1,939 1,939 1,939 1,939Kendall------ - - - -Kenedy606060777777 77 77 77 77Kent------ - - - -Kerr------ - - - -Kimble------ - - - -King------ - - - -Kinney------ - - - -Kleberg------ - - --Knox------ - - - -La Salle------ - - - -Lamar1,3761,3761,3761,3761,3761,376 1,376 1,376 1,376 1,376County2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Winter Generation by CountyThese values are used in the summer import/export calculations for each county. Capacities for mothballed units are included asthe availablecapacity of the unit. Capacities for the wind units are at 8.7%. These values include the amount available for the grid according informationfrom the owners of the private network units and the distributed generation units that have registered with ERCOT.Winter Generation, MWLampasas------ - - - -Lavaca------ - - - -Lee------ - - - -Leon------ - - - -Limestone1,6891,6891,6891,6891,6891,689 1,689 1,689 1,689 1,689Live Oak------ - - - -Llano493493493493493493 493 493 493 493Loving------ - - - -Madison------ - - - -Martin111111111111 11 11 11 11Mason------ - - - -Matagorda2,7502,7502,7502,7502,7502,750 2,750 2,750 2,750 2,750Maverick242424242424 24 24 24 24McCulloch------ - - - -McLennan-925925925925925 925 925 925 925McMullen------ - - - -Medina------ - - - -Menard------ - - - -Midland------ - - - -Milam1,1451,1451,1451,1451,1451,145 1,145 1,145 1,145 1,145Mills------ - - - -Mitchell499499499499499499 499 499 499 499Montague------ - - - -Montgomery555555 5 5 5 5Motley------ - - --Nacogdoches-100100100100100 100 100 100 100Navarro------ - - - -Nolan134134134134134134 134 134 134 134County2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Winter Generation by CountyThese values are used in the summer import/export calculations for each county. Capacities for mothballed units are included asthe availablecapacity of the unit. Capacities for the wind units are at 8.7%. These values include the amount available for the grid according informationfrom the owners of the private network units and the distributed generation units that have registered with ERCOT.Winter Generation, MWNueces2,1812,1842,1842,1842,8043,424 3,424 3,424 3,424 3,424Palo Pinto633633633633633633 633 633 633 633Parker1010---- - - - -Pecos616161616161 61 61 61 61Presidio------ - - - -Rains------ - - - -Reagan------ - - - -Real------ - - - -Red River------ - - - -Reeves------ - - - -Refugio------ - - - -Robertson1,9321,9321,9321,9321,9321,932 1,932 1,932 1,932 1,932Rockwall------ - - - -Runnels------ - - - -Rusk3,3633,3633,3633,3633,3633,363 3,363 3,363 3,363 3,363San Patricio453453453453453453 453 453 453 453San Saba------ - - - -Schleicher------ - - - -Scurry646464646464 64 64 64 64Shackelford494949494949 49 49 49 49Smith------ - - - -Somervell2,4482,4482,4482,4482,4482,448 2,448 2,448 2,448 2,448Starr363636363636 36 36 36 36Stephens------ - - - -Sterling717171717171 71 71 7171Stonewall------ - - - -Sutton------ - - - -Tarrant1,2671,2671,2671,2671,2671,267 1,267 1,267 1,267 1,267County2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20 2020/21Winter Generation by CountyThese values are used in the summer import/export calculations for each county. Capacities for mothballed units are included asthe availablecapacity of the unit. Capacities for the wind units are at 8.7%. These values include the amount available for the grid according informationfrom the owners of the private network units and the distributed generation units that have registered with ERCOT.Winter Generation, MWTaylor110110110110110110 110 110 110 110Terrell------ - - - -Throckmorton------ - - - -Titus1,9501,9501,9501,9501,9501,950 1,950 1,950 1,950 1,950Tom Green131313131313 13 13 13 13Travis1,7061,7361,7361,7361,7361,736 1,736 1,736 1,736 1,736Upton313131313131 31 31 31 31Uvalde------ - - - -Val Verde767676767676 76 76 76 76Van Zandt------ - - - -Victoria544544544544544544 544 544 544 544Waller------ - - - -Ward366366366366366366 366 366 366 366Washington------ - - - -Webb260260260260260260 260 260 260 260Wharton634634634634634634 634 634 634 634Wichita797979797979 79 79 79 79Wilbarger760760760760760760 760 760 760 760Willacy-1818181818 18 18 18 18Williamson------ - - - -Wilson------ - - - -Winkler131313131313 13 13 13 13Wise810810810810810810 810 810 810 810Young615637637637637637 637 637 637 637Zapata------ - - --Zavala------ - - - -Import: The county has less generation than load and must import generationExport: The county has more generation than load and is able to export generationCounty2011/12 2012/13 2013/142014/152015/162016/17 2017/18 2018/19 2019/20 2020/21Anderson-154.5 -157.0 -159.6 -162.0 -163.9 -166.9 -169.6 -171.2 -172.8 -175.3Andrews-123.4 -125.4 -127.5 -129.4 -130.9 -133.3 -135.5 -136.7 -138.0 -140.0Angelina-154.5 -157.8 -161.1 -164.3 -166.8 -170.8 -174.3 -176.3 -178.5 -181.7Aransas-58.7 -59.6 -60.6 -61.5 -62.3 -63.4 -64.4 -65.0 -65.6 -66.6Archer-22.2 -22.5 -22.9 -23.2 -23.5 -23.9 -24.3 -24.5 -24.8 -25.1Atascosa318.5 317.2 316.0 314.8 313.8 312.3 311.0 310.2 309.4 308.2Austin-83.1 -84.4 -85.8 -87.1 -88.1 -89.7 -91.2 -92.0 -92.9 -94.2Bandera-65.4 -66.4 -67.5 -68.5 -69.3 -70.6 -71.7 -72.4 -73.1 -74.2Bastrop1579.4 1576.7 1574.0 1571.5 1569.4 1566.3 1563.5 1561.8 1560.1 1557.5Baylor-4.1 -4.2 -4.2 -4.3 -4.4 -4.4 -4.5 -4.5 -4.6 -4.7Bee-50.3 -51.2 -52.0 -52.8 -53.4 -54.4 -55.3 -55.8 -56.3 -57.1Bell-745.6 -757.8 -770.1 -1.7768.9 754.4 741.5 733.9 726.0 714.0Bexar2106.6 2061.1 2015.0 1971.7 1936.6 1882.7 1834.4 1806.0 1776.5 1731.8Blanco-33.0 -33.5 -34.1 -34.6 -35.0 -35.7 -36.2 -36.6 -36.9 -37.4Borden21.3 21.3 21.3 21.3 21.2 21.2 21.2 21.2 21.2 21.1Bosque826.1 825.4 824.7 824.1 823.5 822.7 821.9 821.5 821.0 820.4Brazoria-1237.2 -1264.1 -1291.4 -1317.0 -1337.9 -1369.8 -1398.3 -1415.2 -1432.7 -1459.1Brazos-147.6 -153.7 -159.9 -165.7 -170.4 -177.7 -184.1 -188.0 -191.9 -197.9Brewster-19.0 -19.3 -19.7 -20.0 -20.2 -20.6 -20.9 -21.1 -21.3 -21.6Brooks-17.0 -17.2 -17.5 -17.8 -18.0 -18.3 -18.6 -18.8 -19.0 -19.2Brown-95.7 -97.2 -98.8 -100.3 -101.5 -103.4 -105.0 -106.0 -107.0 -108.6Burleson-28.8 -29.3 -29.8 -30.2 -30.6 -31.2 -31.6 -31.9 -32.3 -32.7Burnet-19.0 -21.0 -23.0 -24.8 -26.4 -28.7 -30.8 -32.0 -33.3 -35.3Caldwell-95.2 -96.7 -98.3 -99.8 -101.0 -102.8 -104.5 -105.5 -106.5 -108.0Calhoun303.4 332.2 331.0 329.8 328.9 327.5 326.3 325.5 324.7 323.6Winter Import/Export by CountyThis data is presented for example only. It is a calculation of the generation in the county less the projected coincident load in the county. Thetrue values will depend on actual load levels and actual generation dispatch.WinterImport/Export,MWImport: The county has less generation than load and must import generationExport: The county has more generation than load and is able to export generationCounty2011/12 2012/13 2013/142014/152015/162016/17 2017/18 2018/19 2019/20 2020/21Winter Import/Export by CountyThis data is presented for example only. It is a calculation of the generation in the county less the projected coincident load in the county. Thetrue values will depend on actual load levels and actual generation dispatch.WinterImport/Export,MWCallahan-26.5 -27.1 -27.7 -28.3 -28.7 -29.5 -30.1 -30.5 -30.8 -31.4Cameron-506.3 -516.7 -492.4 -502.2 -510.2 -522.5 -533.5 -540.0 -546.7 -556.9Chambers1927.7 1921.7 1915.5 1909.8 1905.1 1897.9 1891.5 1887.7 1883.8 1877.9Cherokee602.9 601.8 600.6 599.5 598.7 597.3 596.1 595.4 594.6 593.5Childress-9.8 -10.0 -10.2 -10.3 -10.4 -10.6 -10.8 -10.9 -11.0 -11.2Clay-21.2 -21.5 -21.9 -22.2 -22.5 -22.9 -23.3 -23.5 -23.7 -24.0Coke-13.9 -14.1 -14.3 -14.6 -14.7 -15.0 -15.2 -15.4 -15.5 -15.8Coleman-29.6 -30.0 -30.5 -31.0 -31.4 -31.9 -32.4 -32.8 -33.1 -33.5Collin-995.1 -1018.1 -1041.5 -1063.4 -1081.2 -1108.5 -1132.9 -1147.4 -1162.3 -1184.9Colorado-68.1 -69.2 -70.4 -71.4 -72.3 -73.6 -74.8 -75.5 -76.2 -77.3Comal-321.4 -326.7 -332.2 -337.3 -341.4 -347.7 -353.4 -356.7 -360.2 -365.5Comanche-35.8 -36.4 -37.0 -37.5 -38.0 -38.7 -39.3 -39.7 -40.1 -40.6Concho-6.7 -6.8 -6.9 -7.0 -7.1 -7.2 -7.3 -7.4 -7.4 -7.6Cooke-103.2 -105.0 -106.9 -108.6 -110.1 -112.3 -114.2 -115.4 -116.6 -118.4Coryell-98.7 -100.3 -102.0 -103.5 -104.8 -106.7 -108.4 -109.4 -110.4 -112.0Cottle-3.0 -3.0 -3.1 -3.1 -3.1 -3.2 -3.3 -3.3 -3.3 -3.4Crane-73.2 -74.4 -75.6 -76.8 -77.7 -79.1 -80.4 -81.1 -81.9 -83.1Crockett-29.9 -30.4 -30.9 -31.4 -31.7 -32.3 -32.8 -33.2 -33.5 -33.9Crosby-1.7 -1.7 -1.7 -1.8 -1.8 -1.8 -1.9 -1.9 -1.9 -1.9Culberson3.2 3.2 3.1 3.1 3.1 3.0 3.0 2.9 2.9 2.9Dallas-3631.5 -3719.3 -3808.1 -3891.6 -3959.3 -4063.2 -4156.2 -4211.0 -4268.0 -4354.0Dawson-31.7 -32.2 -32.8 -33.3 -33.7 -34.3 -34.8 -35.2 -35.5 -36.0Delta-9.3 -9.4 -9.6 -9.7 -9.8 -10.0 -10.2 -10.3 -10.4 -10.5Denton-1273.4 -1294.9 -1316.6 -1337.1 -1353.6 -1379.1 -1401.8 -1415.3 -1429.2 -1450.3Dewitt-58.2 -59.2 -60.2 -61.1 -61.9 -63.0 -64.0 -64.6 -65.3 -66.2Dickens6.8 6.7 6.6 6.5 6.5 6.3 6.2 6.2 6.1 6.0Import: The county has less generation than load and must import generationExport: The county has more generation than load and is able to export generationCounty2011/12 2012/13 2013/142014/152015/162016/17 2017/18 2018/19 2019/20 2020/21Winter Import/Export by CountyThis data is presented for example only. It is a calculation of the generation in the county less the projected coincident load in the county. Thetrue values will depend on actual load levels and actual generation dispatch.WinterImport/Export,MWDimmit-10.9 -11.1 -11.3 -11.4 -11.6 -11.8 -12.0 -12.1 -12.2 -12.4Duval-47.0 -47.8 -48.6 -49.3 -49.9 -50.8 -51.6 -52.1 -52.6 -53.4Eastland-44.4 -45.2 -46.0 -46.8 -47.4 -48.4 -49.3 -49.8 -50.3 -51.1Ector1308.0 1303.2 1298.2 1293.6 1289.8 1284.1 1278.9 1275.8 1272.7 1267.9Edwards-9.0 -9.2 -9.3 -9.5 -9.6 -9.8 -9.9 -10.0 -10.1 -10.2Ellis1124.3 1113.3 1102.1 1091.6 1083.0 1069.9 1058.2 1051.3 1044.2 1033.3Erath-93.9 -95.5 -97.0 -98.5 -99.7 -101.5 -103.1 -104.1 -105.1 -106.6Falls-39.5 -40.1 -40.8 -41.4 -41.9 -42.7 -43.3 -43.8 -44.2 -44.8Fannin1570.5 1569.6 1568.6 1567.7 1566.9 1565.7 1564.7 1564.1 1563.5 1562.5Fayette1784.3 1783.2 1782.0 1781.0 1780.1 1778.8 1777.6 1776.9 1776.2 1775.0Fisher-24.0 -24.4 -24.8 -25.2 -25.5 -25.9 -26.4 -26.6 -26.9 -27.3Floyd5.2 5.2 5.2 5.2 5.2 5.2 5.2 5.2 5.2 5.2Foard-2.5 -2.5 -2.6 -2.6 -2.7 -2.7 -2.7 -2.8 -2.8 -2.8Fort Bend3652.8 3642.7 3632.5 3622.8 3615.0 3603.0 3592.2 3585.9 3579.3 3569.4Franklin-2.4 -2.5 -2.5 -2.6 -2.6 -2.6 -2.7 -2.7 -2.7 -2.8Freestone2198.4 2197.6 2196.8 2196.0 2195.4 2194.4 2193.6 2193.1 2192.6 2191.8Frio254.8 254.4 254.1 253.7 253.4 253.0 252.6 252.4 252.1 251.7Galveston67.8 50.4 32.8 16.2 2.7-17.9 -36.4 -47.3 -58.6 -75.7Gillespie-60.8 -61.8 -62.8 -63.7 -64.5 -65.7 -66.7 -67.3 -68.0 -69.0Glasscock5.5 5.3 5.0 4.8 4.7 4.4 4.2 4.1 3.9 3.7Goliad616.4 616.1 615.7 615.3 615.0 614.5 1274.1 1273.9 1273.6 1273.3Gonzales-45.5 -46.3 -47.1 -47.9 -48.5 -49.5 -50.4 -50.9 -51.4 -52.2Grayson-288.6 -294.7 -300.8 -306.5 -311.2 -318.3 -324.7 -328.5 -332.4 -338.3Grimes1377.1 1376.8 1376.4 1376.0 1375.7 1375.3 1374.9 1374.7 1374.4 1374.1Guadalupe1608.7 1604.2 1599.6 1595.4 1591.9 1586.6 1581.8 1579.0 1576.1 1571.7Hall-1.1 -1.1 -1.2 -1.2 -1.2 -1.2 -1.3 -1.3 -1.3 -1.4Import: The county has less generation than load and must import generationExport: The county has more generation than load and is able to export generationCounty2011/12 2012/13 2013/142014/152015/162016/17 2017/18 2018/19 2019/20 2020/21Winter Import/Export by CountyThis data is presented for example only. It is a calculation of the generation in the county less the projected coincident load in the county. Thetrue values will depend on actual load levels and actual generation dispatch.WinterImport/Export,MWHamilton-16.0 -16.2 -16.5 -16.8 -17.0 -17.3 -17.5 -17.7 -17.9 -18.1Hardeman-10.8 -10.9 -11.1 -11.3 -11.4 -11.6 -11.8 -11.9 -12.0 -12.2Harris-1644.7 -1790.7 -1936.5 -2073.5 -804.7 -975.2 -1127.8 -1217.8 -1311.3 -1452.5Haskell-15.5 -15.7 -16.0 -16.2 -16.4 -16.7 -17.0 -17.1 -17.3 -17.5Hays624.2 618.6 612.9 607.6 603.2 596.6 590.6 587.1 583.4 577.9Henderson65.4 62.8 60.1 57.6 55.6 52.5 49.7 48.1 46.4 43.8Hidalgo746.0 728.3 710.4 693.6 680.0 659.1 640.4 629.4 617.9 600.6Hill-88.8 -90.3 -91.8 -93.1 -94.3 -96.0 -97.5 -98.4 -99.4 -100.8Hood910.6 907.5 904.2 901.2 898.8 895.0 891.6 889.7 887.6 884.5Hopkins-96.4 -98.0 -99.6 -101.1 -102.3 -104.2 -105.9 -106.9 -107.9 -109.4Houston-27.0 -27.5 -27.9 -28.3 -28.7 -29.2 -29.7 -30.0 -30.2 -30.7Howard221.3 220.1 229.3 228.2 227.2 225.8 224.5 223.7 222.9 221.7Hunt-103.9 -107.4 -111.0 -114.3 -117.1 -121.2 -125.0 -127.2 -129.5 -133.0Irion-9.8 -10.0 -10.1 -10.3 -10.4 -10.6 -10.8 -10.9 -11.0 -11.1Jack1217.2 1230.9 1230.6 1230.4 1230.1 1229.8 1229.5 1229.3 1229.1 1228.8Jackson-34.0 -34.6 -35.1 -35.6 -36.1 -36.7 -37.3 -37.7 -38.0 -38.6Jeff Davis-5.5 -5.6 -5.7 -5.7 -5.8 -5.9 -6.0 -6.1 -6.1 -6.2Jim Hogg-3.4 -3.5 -3.5 -3.6 -3.6 -3.7 -3.8 -3.8 -3.8 -3.9Jim Wells-84.2 -85.6 -87.0 -88.3 -89.3 -91.0 -92.4 -93.3 -94.2 -95.5Johnson-62.4 -68.0 -73.7 -79.1 -83.5 -90.2 -96.2 -99.7 -103.3 -108.9Jones-39.4 -40.1 -40.7 -41.4 -41.9 -42.6 -43.3 -43.7 -44.1 -44.8Karnes-24.4 -24.8 -25.2 -25.6 -25.9 -26.4 -26.8 -27.1 -27.3 -27.7Kaufman1622.1 1616.9 1611.7 1606.7 1602.7 1596.6 1591.1 1587.9 1584.5 1579.4Kendall-105.0 -106.7 -108.4 -110.1 -111.4 -113.4 -115.2 -116.3 -117.4 -119.1Kenedy58.3 58.3 58.3 75.8 75.8 75.8 75.8 75.8 75.7 75.7Kent-46.5 -47.2 -48.0 -48.7 -49.3 -50.2 -51.0 -51.5 -52.0 -52.7Import: The county has less generation than load and must import generationExport: The county has more generation than load and is able to export generationCounty2011/12 2012/13 2013/142014/152015/162016/17 2017/18 2018/19 2019/20 2020/21Winter Import/Export by CountyThis data is presented for example only. It is a calculation of the generation in the county less the projected coincident load in the county. Thetrue values will depend on actual load levels and actual generation dispatch.WinterImport/Export,MWKerr-140.2 -142.5 -144.8 -147.0 -148.8 -151.5 -153.9 -155.3 -156.8 -159.1Kimble-15.5 -15.7 -16.0 -16.2 -16.4 -16.7 -17.0 -17.2 -17.3 -17.6King-7.1 -7.2 -7.3 -7.4 -7.5 -7.6 -7.8 -7.8 -7.9 -8.0Kinney-5.4 -5.4 -5.5 -5.6 -5.7 -5.8 -5.9 -5.9 -6.0 -6.1Kleberg-52.3 -53.2 -54.1 -54.9 -55.5 -56.6 -57.5 -58.0 -58.6 -59.4Knox-9.6 -9.8 -9.9 -10.1 -10.2 -10.4 -10.6 -10.7 -10.8 -10.9La Salle-14.3 -14.5 -14.8 -15.0 -15.2 -15.4 -15.7 -15.8 -16.0 -16.2Lamar1248.3 1246.2 1244.1 1242.1 1240.5 1238.1 1235.8 1234.5 1233.2 1231.2Lampasas-50.1 -50.9 -51.8 -52.6 -53.2 -54.2 -55.0 -55.5 -56.1 -56.9Lavaca-29.8 -30.3 -30.8 -31.3 -31.7 -32.2 -32.8 -33.1 -33.4 -33.9Lee-30.0 -30.5 -31.0 -31.4 -31.8 -32.4 -32.9 -33.2 -33.5 -34.0Leon-52.8 -53.7 -54.6 -55.4 -56.1 -57.1 -58.0 -58.5 -59.1 -60.0Limestone1629.6 1628.6 1627.6 1626.7 1625.9 1624.8 1623.7 1623.1 1622.5 1621.6Live Oak-62.3 -63.3 -64.3 -65.3 -66.1 -67.3 -68.4 -69.0 -69.7 -70.7Llano416.5 415.3 414.0 412.8 411.9 410.4 409.1 408.3 407.5 406.2Loving-5.4 -5.5 -5.6 -5.7 -5.8 -5.9 -6.0 -6.0 -6.1 -6.2Madison-5.5 -5.6 -5.7 -5.7 -5.8 -5.9 -6.0 -6.1 -6.1 -6.2Martin-8.9 -9.2 -9.6 -9.9 -10.1 -10.5 -10.8 -11.0 -11.3 -11.6Mason-10.9 -11.1 -11.3 -11.4 -11.6 -11.8 -12.0 -12.1 -12.2 -12.4Matagorda2630.7 2628.7 2626.7 2624.9 2623.4 2621.1 2619.0 2617.8 2616.5 2614.6Maverick-53.4 -54.6 -55.9 -57.1 -58.1 -59.6 -60.9 -61.7 -62.5 -63.8McCulloch-20.9 -21.2 -21.5 -21.9 -22.1 -22.5 -22.9 -23.1 -23.3 -23.7Mclennan-580.4335.1 325.5 316.4 309.1 297.9 287.8 281.9 275.7 266.4Mcmullen-7.8 -7.9 -8.0 -8.2 -8.2 -8.4 -8.5 -8.6 -8.7 -8.8Medina-157.3 -159.8 -162.4 -164.9 -166.9 -169.9 -172.6 -174.3 -175.9 -178.4Menard-6.7 -6.8 -7.0 -7.1 -7.1 -7.3 -7.4 -7.5 -7.5 -7.6Import: The county has less generation than load and must import generationExport: The county has more generation than load and is able to export generationCounty2011/12 2012/13 2013/142014/152015/162016/17 2017/18 2018/19 2019/20 2020/21Winter Import/Export by CountyThis data is presented for example only. It is a calculation of the generation in the county less the projected coincident load in the county. Thetrue values will depend on actual load levels and actual generation dispatch.WinterImport/Export,MWMidland-220.7 -224.3 -228.0 -231.4 -234.2 -238.4 -242.3 -244.5 -246.9 -250.4Milam1086.1 1085.1 1084.2 1083.3 1082.5 1081.4 1080.4 1079.8 1079.1 1078.2Mills-7.8 -7.9 -8.1 -8.2 -8.3 -8.4 -8.6 -8.6 -8.7 -8.9Mitchell482.4 482.2 481.9 481.6 481.4 481.1 480.8 480.6 480.4 480.2Montague-53.3 -54.1 -55.0 -55.9 -56.5 -57.6 -58.5 -59.0 -59.6 -60.4Montgomery-168.5 -171.3 -174.2 -176.8 -179.0 -182.4 -185.4 -187.2 -189.0 -191.8Motley-3.3 -3.4 -3.4 -3.5 -3.5 -3.6 -3.6 -3.7 -3.7 -3.8Nacogdoches-129.8 -31.9 -34.1 -36.1 -37.7 -40.2 -42.5 -43.8 -45.2 -47.3Navarro-151.2 -153.7 -156.2 -158.5 -160.4 -163.3 -166.0 -167.5 -169.1 -171.5Nolan90.0 89.3 88.5 87.9 87.3 86.5 85.7 85.2 84.8 84.1Nueces1349.0 1338.4 1324.6 1311.7 1921.1 2525.0 2510.6 2502.1 2493.3 2479.9Palo Pinto563.8 562.7 561.5 560.4 559.6 558.2 557.0 556.3 555.6 554.5Parker-350.8 -356.7 -372.1 -377.8 -382.3 -389.3 -395.5 -399.2 -403.0 -408.8Pecos-7.1 -8.2 -9.3 -10.4 -11.2 -12.6 -13.7 -14.4 -15.2 -16.2Presidio-10.8 -10.9 -11.1 -11.3 -11.4 -11.6 -11.8 -11.9 -12.0 -12.2Rains-18.4 -18.7 -19.0 -19.3 -19.5 -19.9 -20.2 -20.4 -20.6 -20.8Reagan-15.0 -15.2 -15.4 -15.7 -15.9 -16.2 -16.4 -16.6 -16.7 -17.0Real-12.0 -12.2 -12.4 -12.6 -12.8 -13.0 -13.2 -13.3 -13.4 -13.6Red River-21.5 -21.9 -22.2 -22.6 -22.8 -23.2 -23.6 -23.8 -24.1 -24.4Reeves-17.1 -17.4 -17.7 -18.0 -18.2 -18.5 -18.8 -19.0 -19.2 -19.5Refugio-21.7 -22.1 -22.4 -22.7 -23.0 -23.4 -23.8 -24.0 -24.3 -24.6Robertson1907.6 1907.2 1906.8 1906.4 1906.1 1905.7 1905.2 1905.0 1904.7 1904.3Rockwall-243.3 -247.3 -251.3 -255.1 -258.1 -262.9 -267.1 -269.6 -272.1 -276.0Runnels-25.5 -25.9 -26.4 -26.8 -27.1 -27.6 -28.0 -28.3 -28.5 -28.9Rusk3358.2 3358.1 3358.0 3357.9 3357.9 3357.8 3357.7 3357.6 3357.6 3357.5San Patricio303.9 301.4 298.9 296.6 294.7 291.8 289.3 287.7 286.2 283.8Import: The county has less generation than load and must import generationExport: The county has more generation than load and is able to export generationCounty2011/12 2012/13 2013/142014/152015/162016/17 2017/18 2018/19 2019/20 2020/21Winter Import/Export by CountyThis data is presented for example only. It is a calculation of the generation in the county less the projected coincident load in the county. Thetrue values will depend on actual load levels and actual generation dispatch.WinterImport/Export,MWSan Saba-10.9 -11.0 -11.2 -11.4 -11.5 -11.7 -11.9 -12.0 -12.1 -12.3Schleicher-10.7 -10.9 -11.0 -11.2 -11.3 -11.5 -11.7 -11.8 -11.9 -12.1Scurry-23.8 -25.3 -26.7 -28.1 -29.2 -30.9 -32.4 -33.3 -34.2 -35.6Shackelford38.5 38.3 38.1 38.0 37.8 37.6 37.5 37.3 37.2 37.1Smith-444.0 -451.2 -458.6 -465.5 -471.1 -479.7 -487.4 -491.9 -496.6 -503.7Somervell2421.4 2421.0 2420.5 2420.1 2419.8 2419.3 2418.8 2418.6 2418.3 2417.8Starr-27.1 -28.2 -29.2 -30.2 -31.0 -32.2 -33.3 -34.0 -34.6 -35.6Stephens-54.6 -55.5 -56.4 -57.2 -57.9 -59.0 -59.9 -60.5 -61.1 -62.0Sterling65.2 65.1 65.0 64.9 64.8 64.7 64.6 64.6 64.5 64.4Stonewall-6.6 -6.8 -6.9 -7.0 -7.0 -7.2 -7.3 -7.4 -7.4 -7.5Sutton-16.1 -16.3 -16.6 -16.8 -17.0 -17.3 -17.6 -17.8 -18.0 -18.2Tarrant-2790.8 -2857.1 -2924.3 -2987.4 -3038.7 -3117.2 -3187.5 -3229.0 -3272.1 -3337.1Taylor-142.3 -146.4 -150.6 -154.5 -157.7 -162.6 -167.0 -169.5 -172.2 -176.2Terrell-1.9 -1.9 -1.9 -1.9 -2.0 -2.0 -2.0 -2.1 -2.1 -2.1Throckmorton-6.8 -6.9 -7.1 -7.2 -7.3 -7.4 -7.5 -7.6 -7.6 -7.8Titus1950.0 1950.0 1950.0 1950.0 1950.0 1950.0 1950.0 1950.0 1950.0 1950.0Tom Green-177.0 -180.1 -183.3 -186.3 -188.7 -192.3 -195.6 -197.6 -199.6 -202.6Travis180.7 185.8 160.5 136.8 117.5 88.0 61.5 45.9 29.7 5.3Upton17.0 16.8 16.6 16.3 16.2 15.9 15.7 15.5 15.4 15.2Uvalde-46.7 -47.5 -48.3 -49.0 -49.6 -50.5 -51.3 -51.8 -52.3 -53.0Val Verde-0.6 -1.8 -3.1 -4.3 -5.2 -6.7 -8.0 -8.8 -9.6 -10.9Van Zandt-62.6 -63.6 -64.7 -65.6 -66.4 -67.6 -68.7 -69.4 -70.0 -71.0Victoria340.7 337.4 334.0 330.8 328.3 324.3 320.8 318.7 316.6 313.3Waller-151.9 -154.4 -156.9 -159.3 -161.2 -164.1 -166.8 -168.3 -169.9 -172.4Ward317.9 317.1 316.3 315.6 314.9 314.0 313.2 312.7 312.2 311.4Washington-94.5 -96.0 -97.6 -99.0 -100.2 -102.1 -103.7 -104.7 -105.7 -107.2Import: The county has less generation than load and must import generationExport: The county has more generation than load and is able to export generationCounty2011/12 2012/13 2013/142014/152015/162016/17 2017/18 2018/19 2019/20 2020/21Winter Import/Export by CountyThis data is presented for example only. It is a calculation of the generation in the county less the projected coincident load in the county. Thetrue values will depend on actual load levels and actual generation dispatch.WinterImport/Export,MWWebb-83.2 -88.8 -94.5 -99.8 -104.2 -110.8 -116.8 -120.3 -123.9 -129.4Wharton533.7 532.1 530.4 528.8 527.6 525.6 523.9 522.9 521.8 520.2Wichita-191.8 -196.2 -200.7 -204.9 -208.3 -213.6 -218.3 -221.0 -223.9 -228.2Wilbarger738.3 738.0 737.6 737.3 737.0 736.6 736.2 736.0 735.7 735.4Willacy-30.1 -12.9 -13.4 -13.9 -14.3 -14.9 -15.4 -15.7 -16.0 -16.5Williamson-710.1 -721.7 -733.4 -744.5 -753.4 -767.2 -779.5 -786.7 -794.3 -805.7Wilson-65.6 -66.7 -67.7 -68.8 -69.6 -70.9 -72.0 -72.7 -73.4 -74.4Winkler-27.3 -28.0 -28.7 -29.3 -29.8 -30.6 -31.3 -31.7 -32.1 -32.8Wise598.1 594.6 591.1 587.8 585.1 581.0 577.3 575.2 572.9 569.5Young571.1 592.2 591.4 590.8 590.2 589.4 588.6 588.1 587.7 587.0Zapata-26.9 -27.3 -27.7 -28.2 -28.5 -29.0 -29.5 -29.8 -30.0 -30.5Zavala-18.4 -18.7 -19.0 -19.3 -19.5 -19.9 -20.2 -20.4 -20.6 -20.9