## 1 

# EPA Base Case v.5.1 5 Using IPM

Incremental Documentation

August , 2015



# 1. Introduction

This document describes the updates to the EPA Base Case v.5.1 5 using Integrated Planning Model

(IPM) incremental to the EPA Base Case v.5.1 3 that was developed by the U.S. Environmental Protection

Agency (EPA) with technical support from ICF International, Inc.

This document is a supplemental summary of changes from v.5.13 to v.5.15. For additional information

pertaining to all other sections not identified here, please consult the EPA Base Case v.5.13

documentation (see http://www.epa.gov/powersectormodeling/ ). This document follows the identical

nomenclature for EPA Base Case v.5.13 documentation. The revised sections, tables and figures are

given below.

For ease of use, this document also differentiates updates in the EPA Base Case v.5.15 relative to EPA

Base Case v.5.14 which was released earlier in 2015 (see http://www.epa.gov/powersectormodeling/ ).

Table 1

- 1 that lists updates in EPA Base Case v.5.15 incremental to EPA Base Case v.5.13 and also

differentiates the upd ates that were already included in EPA Base Case v.5.14.

Base Case v.5.1 5 is a projection of electricity sector activity that takes into account f ederal and state air

emission laws and regulations whose provisions were either in effect or enacte d and clearly delineated at

the time the base case was finalized (prior to publication of this documentation) , in addition to two non

- air

federal rules that affect EGUs . Section 3.9 contains a detailed discussion of the environmental

regulations included in EPA Base Case v.5.1 5 , which is summarized below.

• EPA Base Case v.5.1 5 includes the C ross

- State Air Pollution Rule (C SAPR ), a f ederal regulatory

measure for achieving the 1997 National Ambient Air Quality Standards (NAAQS) for ozone and fine

particle s.

• EPA Base Case v.5.1 5 includes current and existing state regulations . A summary of these state

regulations can be found in Table 3

- 13

. In addition to these state regulations, the base case includes

individual permits issued by states.

• EPA Base Case v.5.1 5 includes the Mercury and Air Toxics Rule (MATS), 1 

## which was finalized in

2011. MATS establishes National Emissions Standards for Hazardous Air Pollutants (NESHAPS) for

the “electric utility steam generating unit” source category.

• EPA Base Case v.5.1 5 also reflects the final actions EPA has taken to implement the Regional Haze

Rule. This regulation requires states to submit revised State Implementation Plans (SIPs) that include

(1) goals for improving visibility in Class I areas on the 20% worst days and allowing no degradation

on the 20% best days and (2) assessments and plans for achieving Best Available Retrofit

Technology (BART) emission targets for sources placed in operation between 1962 and 1977. Since

2010, EPA has approved SIPs or, in a very few cases, put in place regional haze Federal

Implementation Plans for several states. The BART limits approved in these plans (as of August,

201 4 ) that will be in place for EGUs are represented in the EPA Base Case v.5.1 5

.

1 

### On June 29, 2015, the U.S. Supreme Court reversed a portion of the U.S. Court of Appeals for the D.C. Circuit (D.C. Circuit)

decision upholding the Mercury and Air Toxics Standards (MATS). Michigan v. EPA, 135 S.Ct. 2699 (2015).

## 2 EPA Base Case v. 5.1 5 also includes two non

- air f ederal rules effecting EGUs: Cooling Water Intakes

(316 ( b ) ) Rule and Combustion Residuals from Electric Utilities (CCR) , both promulgated in 2014

.

Table 1

- 1 lists updates included in EPA Base Case v.5.1 5 incremental to EPA Base Case v.5.13

. Updates that are highlighted in gray were new in EPA Base Case 5.1 5 incremental to EPA Base Case

v .5.14

.

Table 1

- 1 Updates in the EPA Base Case v.5.1 5 incremental to EPA Base Case v.5.1 3

Description For More

Information Change

Type Page

Number

Power System Operation

AEO NEMS region level electricity demand is disaggregated to IPM model region

level Section 3.2 Adding

information 4

AEO 2015 D emand Assumptions Table 3

- 2,

Table 3

- 3 Update 4,5

C SAPR, 316(b) and CCR (in addition to MATS, BART ) are part of Base Case Section 3.9.3 Update 5

AB 32 Regulation Section 3.9.4 Update

assumption 6

Updated State Power Regulations included in EPA Base Case v.5.15 Table 3

- 13 Update 40

Updated NSR Settlements included in EPA Base Case v.5.15 Table 3

- 14 Update 4 9

Updated State Settlements included in EPA Base Case v.5.15 Table 3

- 15 Update 70

Updated Citizen Settlements in EPA Base Case v.5.15 Table 3

- 16 Update 7 3

Updated Renewable Portf olio Standards and Solar Carve

- Outs Table 3

- 17 Update 7 5

Updated BART Regulations included in EPA Base Case v.5.15 Table 3

- 19 Update 7 7

Generating Resources

Cost and Performance Characteristics of Existing Units Section 4.2.7 Adding

Information 7

Updated Data Sources for NEEDS v.5.1 5 Table 4

- 1 Update 8 1

Updated Rules Used in Populating NEEDS v.5.15 Table 4

- 2 Update 8 2

Updated Summary Population (Through 2012) of Existing Units in NEEDS v.5.1 5 Table 4

- 3 Update 8 2

Updated the Hierarchy of Data Sources for Capacity in NEEDS v.5.15 Table 4

- 4 Update 8 3

Updated Data Sources for Unit Configuration in NEEDS v.5.15 Table 4

- 6 Update 8 3

Updated Aggregation Profile of Model Plants Table 4

- 7 Update 8 4

Updated Summary of Planned

- Committed Units in NEEDS v.5.1 5 Table 4

- 11 Update 8 7

Updated Planned

- Committed Units by Model Region in NEEDS v.5.1 5 Table 4

- 12 Update 8 7

Updated Short

- Term Capital Cost Adders for New Power Plants Table 4

- 14 Update 10

Updated Performance and Unit Cost Assumptions for Potential (New) Renewable

and Non

- Conventional Technology Capacity Table 4

- 16 Update 1 1

Updated Representative Wind Generation Profiles Table 4

- 20 Update 1 2

Updated Onshore Reserve Margin Contribution and Average Capacity Factor by

Wind Class Table 4

- 21 Update 1 3

Updated Offshore Shallow Reserve Margin Contribution and Average Capacity

Factor by Wind Class Table 4

- 22 Update 1 3

Offshore Deep Reserve Margin Contribution and Average Capacity Factor by Wind

Class Table 4

- 2 3 Update 1 3

Updated Representative Solar Generation Profiles Table 4

- 2 8 Update 1 4

Updated Solar Reserve Margin Contribution and Average Capacity Factor Table 4

- 2 9 Update 1 5

Updated Nuclear Uprating Table 4

- 33 Update 9 4

Updated Characteristics of Existing Nuclear Units based on NEEDS v.5.1 5 Table 4

- 34 Update 9 4

Updated Capacity not Included based on EIA 860 in NEEDS v.5.1 5 Table 4

- 35 Update 9 8

Updated the Capacity not included due to recent announcements in NEEDS v.5.1 5 Table 4

- 36 Update 17 8

## 3 Description For More

Information Change

Type Page

Number

Added Potential New Powered Dams Table 4

- 37 Added

Information 1 7

Added Potential New Stream Development Table 4

- 38 Added

Information 20

Added Information on Variable O&M and Fixed O&M Cost Approach Section 4.2.7 Added

Information 7

Emission Control Technologies

Added description of CO 2 

## From FGD and DSI Systems Section 5.1 Adding

Information 2 1

Retrofit updates to reflect 2014 behavior in 27 units Section 5.2 Adding

Information 2 1

Natural Gas

Updated List of Key Pipelines Table 10

- 3 Update 2 3

Updated U.S. and Canada Natural Gas Resources and Reserves Table 10

- 4 Update 2 9

Updated Exploration and Development Assumptions Table 10

- 5 Update 30

Updated Resource Cost Curves at the Beginning of Year 2015 Figure 10

- 7 Update 3 2

Updated Incremental E&D Cost (BOY 2015) by Percentage of Dry Gas Resource

Found Figure 10

- 10 Update 3 3

Updated North American LNG Supply Curves Figure 10

- 12 Update 3 4

Updated North American LNG Regasification Facilities Map Figure 10

- 13 Update 3 5

Updated Examples of Firm Demand Curves by Electric Load Segment Figure 10

- 14 Update 3 5

Updated Examples of Interruptible Demand Curves by Electric Load Segment Figure 10

- 15 Update 3 6

Updated LNG Export Assumptions Figure 10

- 16 Update 3 6

Updated 

## New England Pipeline Corridors in 2020 Figure 10

- 17 Update 3 7

Updated 

## Example Pipeline Discount Curve Figure 10

- 18 Update 3 8

Updated 

## Crude Oil and NGL Prices Figure 10

- 22 Update 3 9

Other s

Preventing the Immediate Retirement of Hardwired C2G, Ramping N/A Adding

Information 2 2

## 4 Section 3.2

Methodology to Downscale AEO 201 5 Electricity Demand to EPA v5.1 5 IPM Regions

Electricity demand projections are input at the model region level in IPM. The 22 NEMS regions level

electricity demand from AEO 201 5 is downscaled to 64 EPA Base Case v5.1 5 IPM regions. This

downscaling methodology preserves the sub regional demand projections from AEO 2014 and is

summarized below.

Step 1: Map the Balancing Authorities/ Planning Areas in the US to the 22 NEMS regions and the 64 IPM

regions. The mapping was facilitated by the fact that AEO 201 5 adopted the EGRID regions and EPA

detailed the constituent utilities within each of the 22 EGRID regions.

Step 2: Use year 2007 Balancing Authority level Net

- Energy

- for

- Load data from 2007 Form 714 dataset

and ISO/RTO reports in combination with the mapping developed in Step 1 to develop NEMS

- to

- IPM

region load sharing factors.

Step 3: Apply the NEMS

- to

- IPM region load sharing factors from Step 2 to AEO 201 5 NEMS region level

Net

- Energy

- for

- Load projections to estimate the 64 IPM region level demand projections.

Year Net Energy for Load (Billions of

KWh)

2016 4,051

2018 4,134

2020 4,188

2025 4,328

2030 4,465

2040 4,741

2050 5,036 Table 3-2 Electric Load Assumptions in EPA Base Case v.5.15

Notes:

This data is an aggregation of the model-region-specific net energy

loads used in the EPA Base Case v.5.15.

## 5 Table 3

- 3 National Non

- Coincidental Net Internal Demand in EPA Base Case v.5.1 5

Section 3.9 .3



## CSAPR

The Cross

- State Air Pollution Rule (CSAPR) requires states to significantly improve air quality by

reducing power plant emissions that cross state lines and contribute to ozone and fine particle pollution in

other states. CSAPR requires a total of 28 states to reduce annual SO 2 

## emissions, annual NO X 

## emissions

and/or ozone season NO X 

## emissions to assist in attaining the 1997 ozone and fine particle and 2006 fine

particle National Ambient Air Quality Standards (NAAQS). The timing of CSAPR's implementation has

been affected by a number of cour t actions. On October 23, 2014, the D.C. Circuit granted EPA's request

to lift the stay of CSAPR and revise its implementation schedule, following a favorable decision on the

rule from the Supreme Court. Accordingly, implementation of Phase 1 of CSAPR bega n on January 1,

2015, and implementation of Phase 2 is scheduled to begin on January 1, 2017.

In Phase 1, power plants in the affected states have combined annual emissions budgets of

approximately 3.47 million tons for SO 2 

## , 1.27 million tons for annual N O

x 

## , and 0.63 million tons for ozone

season NO

x



## . These emissions caps will tighten in 2017 when Phase 2 of the program begins. The

Phase 2 combined annual emissions budgets will be 2.26 million tons for SO 2 

## , 1.2 million tons for annual

NO

x 

## , and 0.59 million tons for ozone

- season NO

x 

## . The programs’ assurance provisions, which restrict the

maximum amount of exceedance of an individual state’s emissions budget in a given year through the

use of banked or traded allowances to 18% or 21% of the state’s bud get, will also be implemented

beginning in Phase 2. For more information on CSAPR, go to http://www.epa.gov/crossstaterule/

.

MATS

Finalized in 2011, the Mercury and Air Toxics Rule (MATS) establishes National Emissions Standards for

Hazardous Air Pollutants (NESHAPS) for the “electric utility steam generating unit” source category,

which includes those units that combust coal or oil for the purpose of generating electricity for sale and

distribution through the electric grid to the public. EPA Base Case v.5.15 is identical to EPA Base Case

v.5.13 in its modeling MATS; it applies the input

- based (lbs/MMBtu) MATS control requirements f or

mercury and hydrogen chloride to covered units. Since its release in 2011, EPA has completed multiple

legal actions on this rule as summarized in http://www.epa.gov/mats/actions.html . On June 29, 20 15, the

U.S. Supreme Court reversed a portion of the U.S. Court of Appeals for the D.C. Circuit (D.C. Circuit) Winter Summer

2016 651 736

2018 663 749

2020 673 762

2025 700 793

2030 730 829

2040 793 907

2050 845 967 Peak Demand (GW)

Year

Notes:

This data is an aggregation of the model-region-specific peak demand

loads used in the EPA Base Case v.5.15.

## 6 decision upholding the Mercury and Air Toxics Standards (MATS). Michigan v. EPA, 135 S.Ct. 2699

(2015).

Cooling Water Intakes (316 ( b ) ) Rule

Section 316(b) of the Clean Water Act requires that National Pollutant Discharge Elimination System

(NPDES) permits for facilities with cooling water intake structures ensure that the location, design,

construction, and capacity of the structures reflect t he best technology available to minimize harmful

impacts on the environment. Under a 1995 consent decree with enviro nmental organizations, EPA

divided the section 316(b) rulemaking into three phases. All new facilities except offshore oil and gas

explorat ion facilities were addressed in Phase I in December 2001; all new offshore oil and gas

exploration facilities were later addressed in June 2006 as part of Phase III. This final rule also removes a

portion of the Phase I rule to comply with court rulings. Existing large electric

- generating facilities were

addressed in Phase II in February 2004. Existing small electric

- generating and all manufacturing facilities

were addressed in Phase III (June 2006). However, Phase II and the existing facility portion of Phase III

were remanded to EPA for reconsideration as a result of legal proceedings. This final rule combines

these remands into one rule, and provides a holistic approach to protecting aquatic life impacted by

cooling water intakes. This rule covers roug hly 1,065 existing facilities that are designed to withdraw at

least 2 million gallons per day of cooling water. EPA estimates that 544 power plants are affected by this

rule.

The final regulation has three components for affected facilities: 1) reduce fi sh impingement through a

technology option that meets best technology available requirements, 2) conduct site specific studies to

help determine whether additional controls are necessary to reduce entrainment, and 3) meet

entrainment standards for new unit s at existing facilities when additional capacity is added. EPA Base

Case v.5.1 5 includes cost of complying with this rule by the effected units as detailed in the rule

development. The IPM cost assumptions and analysis for 316(b) can be found in Chapter 8.7 of the

Rule’s Technical Development Document for the Final Section 316(b) Existing Facilities Rule at

http://water.epa.gov/lawsregs/lawsguidance/cwa/316b/upload/Cooling

- Water_Phase

- 4_TDD_2014.pdf

For more information on 316(b) , go to http://water.epa.gov/lawsregs/lawsguidance/cwa/316b/index.cfm

Combustion Residuals from Electric Utilities (CCR)

In December of 2014, EPA finalized national regulations to provide a comprehensive set of requirements

for the safe disposal of coal combustion residuals (CCRs), commonly known as coal ash, from coal

- fired

power plants. The final rule is the culmination of extensive study on the effects of coal ash on the

environment and pu blic health. The rule establishes technical requirements for CCR landfills and surface

impoundments under Subtitle D of the Resource Conservation and Recovery Act.

EPA Base Case v.5.1 5 includes cost of complying with this rule’s requirements by taking t he estimated

plant

- level compliance cost identified in the 2014 RIA for the CCR final rule and apportioning them into

unit

- level cost. Three categories of unit

- level cost were quantified; capital cost, fixed operating and

maintenance cost (FOM), and varia ble operating and maintenance (VOM) cost. The method for

apportioning these costs to the unit

- level for inclusion in EPA Base Case is discussed in the Addendum to

the Regulatory Analysis (RIA) for EPA’s 2015 Coal combustion Residuals (CCR) Final Rule. T he initial

plant

- level cost estimates are discussed in the Rule’s Regulatory Impact Analysis.

For more information on CCR, go to http://www2.epa.gov/coalash/coal

- ash

- rule.

## 7 Section 3.9.4

AB 32

California AB 32 CO 2 

## allowance price projections are based on AEO 2013. The California AB 32 CO 2 

## cost

adder for power imported into CA is based on the CA ARB unspecified rate of 0.428 Metric Tons CO 2 

## /

MWh.

## 8 Section 4.2.7 Cost and Performance Characteristics of Existing Units

VARIABLE O&M APPROACH

EPA Base Case v

. 5.1 5 using IPM uses a modeling construct termed Segmental VOM to capture the

variability in operation and maintenance costs that are treated as a function of the unit’s dispatch pattern.

Generally speaking the construct captures costs associated with major maintenance and consumables. In

EPA Base Case v

. 5.1 5 , the VOM for combined cycles and combustion turbine units includes the costs of

both major maintenance and consumables while for coal steam and oil/gas steam units includes only the

cost of consumables. The VOM cost of various emission control technologies is also incorporated.

Major maintenance 

# : Major maintenance costs are those costs that are required to ma intain the unit at its

delivered performance specifications and whose terms are usually dictated through its long term service

agreement (LTSA). The three main areas of maintenance for gas turbines include combustion inspection,

hot gas path inspection an d major inspections. All of these costs are driven by the hours of operation and

the number of starts that are incurred within that time period of operation. In a cycling or mid

- merit type

mode of operation, there are many starts, accelerating the approac h of an inspection. As more starts are

incurred compared to the generation produced, cost per generation increase. For base load operation

there are fewer starts spread of more generation, lowering the cost per generation. While this nomenclature

is for gas

- turbine based systems, steam turbine based systems have a parallel construct.

Consumables : The model captures consumable costs, as purely a function of output and does not varies

across the segmented time

- period. In other words, the consumables cos t component is held constant over

both peak and off

- peak segments. Consumables include chemicals, lube oils, make

- up water, waste water

disposal, reagents, and purchased electricity.

Data Sources For Gas

- Turbine Based Prime Movers:

ICF has used its deep expertise in operation & maintenance costs for these types of prime movers to

develop generic variable O&M costs as a function of technology.

As mentioned above the variable O&M for gas

- turbine based systems tracks Long Term Service Agreement

costs, star t

- up and consumables.

Data Sources For Stand

- Alone Steam Turbine Based Prime Movers:

The value levels of non

- fuel variable O&M data for stand

- alone steam turbine plants is mostly based on

2010 NETL Report, “Cost and Performance Baseline for Fossil Energy Plants” supplemented with ICF

experience where required. The VOM cost adders of various emission control technologies are based on

cost functions described in Chapter 5.

FIXED O&M APPROACH



# Stand Alone

– Steam Turbines Based Prime Movers

IPM’s O&M cost data for existing coal and oil/gas steam units were developed starting with FERC Form 1

data sets from the years 2003 to 2012. The FERC Form

- 1 database does not explicitly report separate

fixed and variable O&M expenses. In deriving Fixed O&M costs, generi c variable O&M costs are assigned

to each individual power plant. Next, the assumed variable O&M cost is subtracted from the total O&M

reported by FERC Form

- 1 to calculate a starting point for fixed O&M. Thereafter other cost items which are

not reported b y FERC Form

- 1, are added to the raw FOM starting point. These unreported cost items are

SG&A ( Selling, General and Administrative Expenses) , property taxes, insurance and routine capex. A

detailed description of the fixed O&M derivation methodology is prov ided below.

## 9 

# Exhibit

- 1

Derivation of Plant Fixed O&M Data

i) Assign generic VOM cost to each unit in FERC Form 1. Subtract this VOM from the total O&M

cost from FERC Form 1 to calculate raw FOM cost. Aggregate this unit level raw FOM cost

data into age based categories. The weighted average raw FOM costs for uncontrolled units

by age group is the output of this st ep and is used as the starting point for subsequent steps.

ii) An owner/operator fee for SG&A services in the range of 20

- 30% is added to raw fixed O&M

figures in step 1.

iii) Property tax and insurance cost estimates in $/kW

- yr are also added. These figures var y by

plant type.

iv) A generic percentage value to cover routine capex is added to raw fixed O&M figures in step

1. The percentage varies by prime mover and is based on a review of FERC Form 1 data

v) Finally, generic FOM cost adders for various emission contro l technologies are estimated using

cost functions described in Chapter 5. Based on the emission control configuration of each unit

in NEEDS, the appropriate emission control cost adder is added to the raw cost from step 1.

The fixed O&M derivation approac h relies on top

- down derivation of fixed costs based on FERC Form

- 1

data and ICF’s own non

- fuel variable O&M , SG&A, routine capex, property tax and insurance.



# Gas

- Turbine Based Prime Movers

Similar to the stand

- alone steam turbine based prime movers, the Fixed O&M for gas

- turbine based

systems tracks: labor, routine maintenance, property taxes, insurance, owner/operator SG&A, and routine

capital expenditures. These generic Fixed O&M costs as a function of technology are based on ICF’s deep

expertise in fixed operation & maintenance costs for these types of prime movers. Get FERC

FORM

- 1

O&M data Calculate

FOM by

subtracting

non

- fuel

VOM from

O&M Add SG&A,

routine

CapEx

, property taxes

and insurance

## 10 Table 4

- 14 Short

- Term Capital Cost Adders for New Power Plants in EPA Base Case v.5.15 (2011$)

Step 1 Step 2 Step 3 Step 1 Step 2 Step 3 Step 1 Step 2 Step 3 Step 1 Step 2 Step 3 Step 1 Step 2 Step 3

Upper Bound (MW) 658 438

- 1,315 877

- 1,315 877

- 3,288 2,192

- 3,288 2,192

- Adder ($/kW)

- 1,285 3,322

- 1,285 3,322

- 1,285 3,322

- 1,285 3,322

- 1,285 3,322

Upper Bound (MW) 6,913 4,609

- 13,826 9,218

- 13,826 9,218

- 34,566 23,044

- 34,566 23,044

- Adder ($/kW)

- 916 2,370

- 916 2,370

- 916 2,370

- 916 2,370

- 916 2,370

Upper Bound (MW) 46,157 30,771

- 92,314 61,542

- 92,314 61,542

- 230,784 153,856

- 230,784 153,856

- Adder ($/kW)

- 313 809

- 313 809

- 313 809

- 313 809

- 313 809

Upper Bound (MW) 23,668 15,778

- 47,335 31,557

- 47,335 31,557

- 118,338 78,892

- 118,338 78,892

- Adder ($/kW)

- 200 518

- 200 518

- 200 518

- 200 518

- 200 518

Upper Bound (MW) 600 400

- 1,200 800

- 1,200 800

- 3,000 2,000

- 3,000 2,000

- Adder ($/kW)

- 2,215 5,727

- 2,215 5,727

- 2,215 5,727

- 2,215 5,727

- 2,215 5,727

Upper Bound (MW) 314 210

- 629 419

- 629 419

- 1,572 1,048

- 1,572 1,048

- Adder ($/kW)

- 2,140 5,535

- 2,133 5,517

- 2,133 5,517

- 2,113 5,465

- 2,088 5,400

Upper Bound (MW) 2,400 1,600

- 4,800 3,200

- 4,800 3,200

- 12,000 8,000

- 12,000 8,000

- Adder ($/kW)

- 944 2,441

- 944 2,441

- 944 2,441

- 944 2,441

- 944 2,441

Upper Bound (MW) 600 400

- 1,200 800

- 1,200 800

- 3,000 2,000

- 3,000 2,000

- Adder ($/kW)

- 2,708 7,003

- 2,701 6,987

- 2,701 6,987

- 2,683 6,939

- 2,660 6,879

Upper Bound (MW) 11,244 7,496

- 22,488 14,992

- 22,488 14,992

- 56,220 37,480

- 56,220 37,480

- Adder ($/kW)

- 1,789 4,626

- 1,789 4,626

- 1,789 4,626

- 1,789 4,626

- 1,789 4,626

Upper Bound (MW) 920 614

- 1,841 1,227

- 1,841 1,227

- 4,602 3,068

- 4,602 3,068

- Adder ($/kW)

- 1,382 3,575

- 1,357 3,511

- 1,334 3,450

- 1,273 3,292

- 1,208 3,125

Upper Bound (MW) 7,441 4,961

- 14,882 9,922

- 14,882 9,922

- 37,206 24,804

- 37,206 24,804

- Adder ($/kW)

- 607 1,569

- 521 1,347

- 436 1,128

- 396 1,025

- 355 919

Upper Bound (MW) 15,700 10,466

- 31,399 20,933

- 31,399 20,933

- 78,498 52,332

- 78,498 52,332

- Adder ($/kW)

- 523 1,352

- 514 1,330

- 507 1,310

- 492 1,274

- 485 1,253

Upper Bound (MW) 600 400

- 1,200 800

- 1,200 800

- 3,000 2,000

- 3,000 2,000

- Adder ($/kW)

- 1,589 4,111

- 1,504 3,891

- 1,421 3,674

- 1,248 3,226

- 1,207 3,122

Upper Bound (MW) 1,451 967

- 2,902 1,934

- 2,902 1,934

- 7,254 4,836

- 7,254 4,836

- Adder ($/kW)

- 504 1,303

- 504 1,303

- 504 1,303

- 504 1,303

- 504 1,303 Offshore Wind

Nuclear

Solar Thermal

Onshore Wind 2030

9

10

11 Solar PV Plant Type 2016 2018 2020 2025

6

7

8 IGCC and Advanced Coal with

Carbon Capture

Landfill Gas

13 ID Number

Biomass

Coal Steam

14 Hydro 12 1

2

3

4

5 Combined Cycle

Combustion Turbine

Fuel Cell

Geothermal

## 11 LGHI LGLo LGVLo

Size (MW) 50 50 10 150 100 100 400

First Year Available 2018 2018 2020 2016 2016 2018 2016 2020

Lead Time (Years) 3 4 4 3 2 3 3 4

Availability 83% 87% 90% 87% 90% 90% 95% 95%

Generation Capability Economic Dispatch Economic Dispatch Economic Dispatch Economic Dispatch Generation Profile Generation Profile Generation Profile Generation Profile

Heat Rate (Btu/kWh) 13,500 30,000 13,648 13,648 13,648 9,246 9,756 9,756 9,756 9,756

Capital (2011$/kW) 4,041 1,187 - 15,752 8,408 10,594 16,312 1,170 - 6,541 7,117 2,145 4,929 1,695 5,153

Fixed O&M (2011$/kW/yr) 103.79 50 - 541 381.74 381.74 381.74 14.60 357.47 7.37 42.20 46.50 101.40

Variable O&M (2011$/MWh) 5.17 0.00 8.51 8.51 8.51 2.60 0.0 0.0 0.0 0.0 0.0

Heat Rate (Btu/kWh) 8,738 9,756 9,756 9,756 9,756

Capital (2011$/kW) 6995 1,848 4,851 1,688 4885

Fixed O&M (2011$/kW/yr) 357.5 7.37 42.20 46.50 101.40

Variable O&M (2011$/MWh) 0.0 0.0 0.0 0.0 0.0

Heat Rate (Btu/kWh) 8,230 9,756 9,756 9,756 9,756

Capital (2011$/kW) 6806 1,552 4,774 1,682 4617

Fixed O&M (2011$/kW/yr) 357.5 7.37 42.20 46.50 101.40

Variable O&M (2011$/MWh) 0.0 0.0 0.0 0.0 0.0

Heat Rate (Btu/kWh) 6,960 9,756 9,756 9,756 9,756

Capital (2011$/kW) 6276 1,423 4,580 1,672 4070

Fixed O&M (2011$/kW/yr) 357.5 7.37 42.20 46.50 101.40

Variable O&M (2011$/MWh) 0.0 0.0 0.0 0.0 0.0

Heat Rate (Btu/kWh) 6,960 9,756 9,756 9,756 9,756

Capital (2011$/kW) 5,799 1,294 4,387 1,668 3963

Fixed O&M (2011$/kW/yr) 357.5 7.37 42.20 46.50 101.40

Variable O&M (2011$/MWh) 0.0 0.0 0.0 0.0 0.0

Heat Rate (Btu/kWh) 6,960 9,756 9,756 9,756 9,756

Capital (2011$/kW) 4,872 1,035 3,999 1,667 3,862

Fixed O&M (2011$/kW/yr) 357.5 7.37 42.20 46.50 101.40

Variable O&M (2011$/MWh) 0.0 0.0 0.0 0.0 0.0

Heat Rate (Btu/kWh) 6,960 9,756 9,756 9,756 9,756

Capital (2011$/kW) 4872 1,035 3,612 1,667 3747

Fixed O&M (2011$/kW/yr) 357.5 7.37 42.20 46.50 101.40

Variable O&M (2011$/MWh) 0.0 0.0 0.0 0.0 0.0 Table 4-16 Performance and Unit Cost Assumptions for Potential (New) Renewable and Non-Conventional Technology Capacity in EPA Base Case v.5.15

Vintage #2 (2018)

Vintage #3 (2020)

Vintage #4 (2025)

Vintage #5 (2030) Solar Thermal Onshore Wind Offshore Wind

50

2016

3 Hydro

Vintage #1 (2016-2054)

Notes:

1 Assumptions for Biomass Cofiring for Coal Plants can be found in Table 5-13 Biomass-Bubbling

Fluidized Bed (BFB) Geothermal Landfill Gas Fuel Cells Solar Photovoltaic

Vintage #7 (2050) Vintage #6 (2040) 90%

Economic Dispatch

Vintage #1 (2016)

## 12 1 2 3 4 5 1 2 3 4 5

01 496 577 628 639 678 01 331 389 480 500 541

02 490 570 622 634 674 02 318 374 465 487 530

03 484 566 619 631 670 03 306 362 452 473 518

04 470 551 606 619 661 04 284 340 427 449 495

05 443 524 580 596 642 05 252 307 389 411 458

06 426 505 560 579 628 06 227 279 357 378 426

07 422 500 553 573 623 07 207 254 328 349 396

08 430 509 558 578 628 08 201 245 317 338 384

09 420 501 548 569 619 09 193 236 303 326 370

10 401 485 532 555 607 10 196 243 304 328 374

11 387 470 518 544 597 11 211 262 317 343 392

12 384 466 514 542 596 12 231 284 333 359 410

13 384 463 510 540 595 13 244 296 341 366 417

14 387 464 511 541 596 14 254 304 344 368 420

15 390 464 512 542 597 15 262 311 348 372 422

16 386 458 504 535 591 16 264 312 348 372 422

17 373 444 487 519 577 17 260 306 343 367 415

18 374 446 485 518 576 18 267 312 349 373 419

19 403 476 514 545 600 19 292 338 381 405 448

20 447 522 561 587 636 20 325 374 427 450 491

21 479 557 598 617 660 21 344 397 462 484 523

22 497 576 619 634 673 22 350 406 482 501 541

23 502 582 629 641 679 23 347 405 488 507 547

24 500 580 629 641 679 24 340 399 487 506 547

Winter

Average 432 511 558 580 628 Summer

Average 271 322 386 409 454

Notes:

Based on Onshore Wind in Model Region WECC_CO.

This is an example of the wind data used in EPA Base Case v.5.15 Table 4-20 Representative Wind Generation Profiles in EPA Base Case v.5.15

Illustrative Hourly Wind Generation Profile (kWh of Generation per MW of Electricity)

Winter

Hour Wind Class Summer

Hour Wind Class

## 13 1 2 3 4 5

Capacity Factor 36% 43% 49% 51% 56%

Reserve Margin Contribution 1 

## 24% 29% 32% 34% 37%



# Note:

1 

## Reserve Margin Contribution for ERC_REST and ERC_WEST is 8.7%. Wind Class Table 4-21 Onshore Reserve Margin Contribution and Average Capacity Factor

by Wind Class

1 2 3 4 5

Capacity Factor 

# 31% 40% 43% 47% 52%

Reserve Margin Contribution 1 

## 20% 26% 29% 31% 34%



# Note:

1 

## Reserve Margin Contribution for ERC_REST and ERC_WEST is 8.7%. Wind Class Table 4-22 Offshore Shallow Reserve Margin Contribution and Average Capacity

Factor by Wind Class



## 1 2 3 4 5

Capacity Factor 36% 45% 49% 51% 54%

Reserve Margin Contribution 1 

## 24% 30% 32% 34% 35%



# Note:

1 

## Reserve Margin Contribution for ERC_REST and ERC_WEST is 8.7%. Wind Class Table 4-23 Offshore Deep Reserve Margin Contribution and Average Capacity

Factor by Wind Class

## 14 Winter

Hour Solar

Thermal Solar

Photovoltaic Summer

Hour Solar

Thermal Solar

Photovoltaic

01 0 0 01 0 3

02 0 0 02 0 3

03 0 0 03 0 3

04 0 0 04 0 3

05 0 0 05 0 3

06 0 446 06 3 574

07 48 446 07 475 574

08 325 446 08 911 574

09 588 446 09 978 574

10 633 446 10 993 574

11 579 446 11 959 574

12 554 446 12 935 574

13 562 552 13 890 600

14 615 552 14 876 600

15 667 552 15 852 600

16 514 552 16 819 600

17 166 64 17 651 155

18 1 64 18 185 155

19 0 64 19 0 155

20 0 64 20 0 155

21 0 64 21 0 155

22 0 0 22 0 3

23 0 0 23 0 3

24 0 0 24 0 3

Winter

Average 219 236 Summer

Average 397 301 Table 4-28 Representative Solar Generation Profiles in EPA Base v.5.15

Illustrative Hourly Solar Generation Profile (kWh of Generation per MW of Electricity)

Note:

Based on model region WECC_AZ, Solar class 4

This is an example of the solar data used in EPA Base Case v.5.15

## 15 Table 4

- 29 Solar Reserve Margin Contribution and Average Capacity Factor



# State Solar Photovoltaic

Average Capacity

Factor Reserve Margin Contribution

Alabama 20% 23%

Alaska 11% 12%

Arizona 26% 30%

Arkansas 21% 24%

California 25% 29%

Colorado 26% 30%

Connecticut 18% 21%

Delaware 19% 21%

Florida 21% 24%

Georgia 20% 23%

Hawaii 21% 24%

Idaho 22% 25%

Illinois 19% 21%

Indiana 18% 21%

Iowa 20% 23%

Kansas 24% 27%

Kentucky 19% 21%

Louisiana 20% 22%

Maine 19% 22%

Maryland 18% 20%

Massachusetts 18% 21%

Michigan 17% 20%

Minnesota 19% 22%

Mississippi 20% 22%

Missouri 19% 22%

Montana 21% 24%

Nebraska 22% 25%

Nevada 26% 30%

New Hampshire 18% 21%

New Jersey 20% 23%

New Mexico 26% 30%

New York 18% 21%

North Carolina 21% 23%

North Dakota 20% 23%

Ohio 17% 20%

Oklahoma 22% 25%

Oregon 23% 26%

Pennsylvania 18% 20%

Rhode Island 18% 20%

South Carolina 20% 23%

South Dakota 21% 24%

Tennessee 20% 23%

Texas 22% 25%

Utah 25% 28%

Vermont 18% 20%

Virginia 20% 23%

Washington 20% 23%

West Virginia 17% 20%

Wisconsin 18% 21%

Wyoming 23% 26%

## 16 

# Average Capacity Factor Reserve Margin Contribution

Alabama 20% 23%

Alaska 11% 12%

Arizona 26% 30%

Arkansas 21% 24%

California 25% 29%

Colorado 26% 30%

Connecticut 18% 21%

Delaware 19% 21%

Florida 21% 24%

Georgia 20% 23%

Hawaii 21% 24%

Idaho 22% 25%

Illinois 19% 21%

Indiana 18% 21%

Iowa 20% 23%

Kansas 24% 27%

Kentucky 19% 21%

Louisiana 20% 22%

Maine 19% 22%

Maryland 18% 20%

Massachusetts 18% 21%

Michigan 17% 20%

Minnesota 19% 22%

Mississippi 20% 22%

Missouri 19% 22%

Montana 21% 24%

Nebraska 22% 25%

Nevada 26% 30%

New Hampshire 18% 21%

New Jersey 20% 23%

New Mexico 26% 30%

New York 18% 21%

North Carolina 21% 23%

North Dakota 20% 23%

Ohio 17% 20%

Oklahoma 22% 25%

Oregon 23% 26%

Pennsylvania 18% 20%

Rhode Island 18% 20%

South Carolina 20% 23%

South Dakota 21% 24%

Tennessee 20% 23%

Texas 22% 25%

Utah 25% 28%

Vermont 18% 20%

Virginia 20% 23%

Washington 20% 23%

West Virginia 17% 20%

Wisconsin 18% 21%

Wyoming 23% 26%



# State Solar Photovoltaic

## 17 Table 4

- 37 Potential N on P owered D ams



# IPM Region State Capacity

(MW) Capital Cost

(2011$/kW) FOM

(2011$/kW

yr) VOM

(2011mills/kWh)

ERC_REST Texas 383 2245 14.6 2.60

ERC_WEST Texas 29 2183 14.6 2.60

FRCC Florida 126 2270 14.6 2.60

MIS_IA Iowa 383 1707 14.6 2.60

MIS_IL Illinois 630 1504 14.6 2.60

MIS_INKY Indiana 66 2753 14.6 2.60

Kentucky 536 1271 14.6 2.60

MIS_LMI Michigan 32 4081 14.6 2.60

MIS_MAPP Montana 17 2159 14.6 2.60

North Dakota 15 2548 14.6 2.60

MIS_MIDA Illinois 48 1552 14.6 2.60

Iowa 150 1711 14.6 2.60

MIS_MNWI Michigan 0.04 4396 14.6 2.60

Minnesota 123 2227 14.6 2.60

Wisconsin 101 1993 14.6 2.60

MIS_MO Iowa 4 1808 14.6 2.60

Missouri 242 1454 14.6 2.60

MIS_WUMS Michigan 4 4415 14.6 2.60

Wisconsin 114 1859 14.6 2.60

NENG_CT Connecticut 59 2934 14.6 2.60

NENG_ME Maine 15 4898 14.6 2.60

NENGREST Massachusetts 53 4531 14.6 2.60

New Hampshire 56 3046 14.6 2.60

Rhode Island 11 4423 14.6 2.60

Vermont 13 3137 14.6 2.60

NY_Z_A&B New York 20 2329 14.6 2.60

NY_Z_C&E New York 66 2461 14.6 2.60

NY_Z_D New York 49 2437 14.6 2.60

NY_Z_F New York 78 2478 14.6 2.60

NY_Z_G

- I New York 28 2275 14.6 2.60

PJM_AP Maryland 13 2689 14.6 2.60

Pennsylvania 237 1988 14.6 2.60

Virginia 3 3475 14.6 2.60

West Virginia 138 1927 14.6 2.60

PJM_ATSI Ohio 64 2714 14.6 2.60

Pennsylvania 43 1842 14.6 2.60

PJM_COMD Illinois 150 1899 14.6 2.60

PJM_Dom North Carolina 4 2649 14.6 2.60

Virginia 13 2939 14.6 2.60

## 18 

# IPM Region State Capacity

(MW) Capital Cost

(2011$/kW) FOM

(2011$/kW

yr) VOM

(2011mills/kWh)

PJM_EMAC Delaware 1 4655 14.6 2.60

Maryland 13 2387 14.6 2.60

New Jersey 17 4291 14.6 2.60

Pennsylvania 9 2476 14.6 2.60

PJM_PENE Pennsylvania 316 2026 14.6 2.60

PJM_SMAC District of

Columbia 1 2969 14.6 2.60

Maryland 15 3092 14.6 2.60

PJM_West Indiana 10 2612 14.6 2.60

Kentucky 68 2166 14.6 2.60

Michigan 0.3 4770 14.6 2.60

Ohio 165 2543 14.6 2.60

Tennessee 0.3 2778 14.6 2.60

Virginia 8 2473 14.6 2.60

West Virginia 37 2166 14.6 2.60

PJM_WMAC Pennsylvania 49 2648 14.6 2.60

S_C_KY Kentucky 431 1551 14.6 2.60

Ohio 5 2446 14.6 2.60

S_C_TVA Alabama 118 1628 14.6 2.60

Georgia 30 1764 14.6 2.60

Kentucky 1032 1170 14.6 2.60

Mississippi 112 2083 14.6 2.60

North Carolina 2 3646 14.6 2.60

Tennessee 21 2523 14.6 2.60

Virginia 1 2468 14.6 2.60

S_D_AMSO Louisiana 158 1599 14.6 2.60

S_D_N_AR Arkansas 599 1556 14.6 2.60

Missouri 11 2243 14.6 2.60

S_D_REST Arkansas 144 1653 14.6 2.60

Louisiana 192 1629 14.6 2.60

Mississippi 58 1974 14.6 2.60

S_D_WOTA Louisiana 23 1727 14.6 2.60

Texas 125 1509 14.6 2.60

S_SOU Alabama 723 1324 14.6 2.60

Florida 11 2307 14.6 2.60

Georgia 51 1910 14.6 2.60

Mississippi 56 1941 14.6 2.60

S_VACA Georgia 0.1 2178 14.6 2.60

North Carolina 111 2553 14.6 2.60

South Carolina 43 2973 14.6 2.60

SPP_N Kansas 54 2421 14.6 2.60

## 19 

# IPM Region State Capacity

(MW) Capital Cost

(2011$/kW) FOM

(2011$/kW

yr) VOM

(2011mills/kWh)

Missouri 7 2564 14.6 2.60

SPP_NEBR Kansas 3 2460 14.6 2.60

SPP_SE Louisiana 451 1537 14.6 2.60

SPP_SPS New Mexico 14 2501 14.6 2.60

SPP_WEST Arkansas 387 1548 14.6 2.60

Louisiana 24 1614 14.6 2.60

Missouri 0.4 2809 14.6 2.60

Oklahoma 312 1816 14.6 2.60

Texas 20 2174 14.6 2.60

WEC_CALN California 110 2559 14.6 2.60

WEC_LADW California 27 1993 14.6 2.60

WECC_AZ Arizona 58 2171 14.6 2.60

WECC_CO Colorado 146 1860 14.6 2.60

WECC_ID Idaho 6 3542 14.6 2.60

WECC_IID California 0.4 1708 14.6 2.60

WECC_MT Montana 54 2832 14.6 2.60

WECC_NM New Mexico 75 2329 14.6 2.60

Texas 15 2443 14.6 2.60

WECC_NNV Nevada 12 4012 14.6 2.60

WECC_PNW California 4 3244 14.6 2.60

Idaho 1 2985 14.6 2.60

Oregon 96 2709 14.6 2.60

Washington 70 2464 14.6 2.60

WECC_SCE California 34 1911 14.6 2.60

WECC_SF California 1 2911 14.6 2.60

WECC_SNV Nevada 2 3508 14.6 2.60

WECC_UT Utah 29 2315 14.6 2.60

WECC_WY Wyoming 37 2157 14.6 2.60

## 20 Table 4

- 38 Potential New Stream Development



# IPM Region State Capacity

(MW) Capital Cost

(2011$/kW) FOM

(2011$/kW

- yr) VOM

(2011mills/kWh)

MIS_MO Missouri 891 3500 14.6 2.60

NENG_ME Maine 406 5750 14.6 2.60

NENGREST Massachusetts 13 5445 14.6 2.60

New

Hampshire 117 4838 14.6 2.60

Vermont 58 5673 14.6 2.60

PJM_AP Pennsylvania 7 4484 14.6 2.60

PJM_EMAC New Jersey 43 4995 14.6 2.60

Pennsylvania 30 4484 14.6 2.60

PJM_PENE Pennsylvania 239 4061 14.6 2.60

PJM_SMAC Maryland 79 4862 14.6 2.60

PJM_WMAC Pennsylvania 653 3972 14.6 2.60

S_VACA South Carolina 51 5470 14.6 2.60

SPP_N Missouri 350 3427 14.6 2.60

WECC_NNV Nevada 13 6541 14.6 2.60

WECC_PNW Oregon 86 4518 14.6 2.60

Washington 394 3873 14.6 2.60

## 21 Section 5.1

Carbon dioxide (CO 2 

## ) Emissions from Chemical Reactions in a Wet Flue Gas Desulfurization (FGD)

System for Sulfur Dioxide (SO 2 

## ) Control:

In EPA applications of IPM, the chemical reactions in a limestone forced oxidation (LSFO) system (also

known as a wet FGD or wet scrubber) are assumed to cause CO 2 

## increases according to the following

equation:

CO 2 

## increase in % of total CO 2 

## from fuel = 0.35 * SO 2 

## emission rate of the fuel (in lb/MMBtu)

– 0.02

For example, for coal with an SO 2 

## emission factor of 4.3 lb/MMBtu, the increase in CO 2 

## is 1.485%. In

contrast to LSFO, there is no representation of direct emissions of CO 2 

## or other greenhouse gases from

the other control technologies in IPM. These include limestone spray dryers (LSD) for SO 2 

## control, dry

sorbent injection (DSI) for SO 2 

## and hydrogen chloride (HCl) control, selective catalytic reduction (SCR)

and selective no n

- catalytic reduction (SNCR) for NO

x 

## control, and activated carbon injection (ACI) for

mercury control.

Section 5.2

Retrofit updates to reflect 2014 behavior in 27 units

In recent years, some units have operated SCRs at reduced efficiency, or even bypassed SCRs

altogether. As SCR rates in IPM for existing units are drawn from 2011 historical rates, this could

overstate reductions at these units. To evaluate, EPA looked at units to determine where 2014 ozone

season NOx rates had significantly increased from their 2011 values. Specifically, if a unit both had an

SCR in 2011 and subsequently increased their ozone season NOx rate by at least 45% in 2014 their NOx

rate was marked for close examination.

NO

x 

## rates and SCR (or SNCR) operation behavior for selected units were revised to reflect 2014 ETS

data. The following table shows each unit’s respective revised NO

x 

## rates and control operation.

## 22 Retrofit Updates to Reflect 2014 Behavior in 27 Units

Facility UniqueID State Control Control

Operation

Assumed

in 2014 M1 M2 M3 M4

Alcoa Allowance Management

Inc 6705_B_4 IN SCR Off 0.29 0.14 0.29 0.14

Belews Creek 8042_B_2 NC SCR On 0.10 0.10 0.10 0.10

Bruce Mansfield 6094_B_3 PA SCR Off 0.28 0.08 0.28 0.08

Charles R Lowman 56_B_3 AL SCR Off 0.36 0.07 0.36 0.07

East Bend 6018_B_2 KY SCR Off 0.24 0.12 0.24 0.12

Elmer Smith 1374_B_1 KY SCR Off 0.99 0.07 0.99 0.07

G G Allen 2718_B_3 NC SNCR Off 0.36 0.21 0.36 0.21

G G Allen 2718_B_4 NC SNCR Off 0.35 0.21 0.35 0.21

Gen J M Gavin 8102_B_1 OH SCR On 0.14 0.14 0.14 0.14

Ghent 1356_B_3 KY SCR On 0.19 0.19 0.19 0.19

Ghent 1356_B_4 KY SCR On 0.18 0.18 0.18 0.18

Harrison Power Station 3944_B_1 WV SCR Off 0.35 0.19 0.35 0.19

Homer City 3122_B_1 PA SCR Off 0.35 0.19 0.35 0.19

Homer City 3122_B_3 PA SCR Off 0.42 0.19 0.42 0.19

John E Amos 3935_B_3 WV SCR On 0.10 0.10 0.10 0.10

Marshall 2727_B_3 NC SCR On 0.14 0.14 0.14 0.14

Mayo 6250_B_1A NC SCR On 0.15 0.15 0.15 0.15

Mayo 6250_B_1B NC SCR On 0.15 0.15 0.15 0.15

Mill Creek 1364_B_3 KY SCR Off 0.23 0.07 0.23 0.07

New Madrid Power Plant 2167_B_2 MO SCR Off 0.47 0.10 0.47 0.10

Pleasants Power Station 6004_B_2 WV SCR Off 0.37 0.13 0.37 0.13

Roxboro 2712_B_2 NC SCR On 0.15 0.15 0.15 0.15

St. Johns River Power 207_B_1 FL SCR Off 0.37 0.15 0.37 0.15

St. Johns River Power 207_B_2 FL SCR Off 0.34 0.15 0.34 0.15

Thomas Hill Energy Center 2168_B_MB1 MO SCR Off 0.55 0.15 0.55 0.15

Thomas Hill Energy Center 2168_B_MB3 MO SCR Off 0.22 0.11 0.22 0.11

Trimble County 6071_B_1 KY SCR On 0.14 0.14 0.14 0.14



## Preventing the Immediate Retirement of Hardwired Coal

- to

- gas (C2G) Converting Plants

Hardwired C2G retrofits in NEEDS and in the run are prevented from retiring based on a n exogenous

ramp rate. The limits are calculated based on the assumption that none of the units can retire in 2014 and

all of them can retire in 2030. The following limits in MW of coal

- to

- gas retrofitting capacity that may be

retired in each run

- year were applied be fore 2030

.

Year Limit (MW)

2016 2,194

2018 4,388

2020 6,852

2025 12,066

## 23 Chapter 10

Table 10

- 3 List of Key Pipelines

Link Pipeline

1

- 4 Iroquois Pipeline Co

1

- 81 Maritimes & Northeast Pipeline

1

- 104 Tennessee Gas Pipeline Co

1

- 104 Algonquin Gas Trans Co

3

- 104 Iroquois Pipeline Co

5

- 6 Tennessee Gas Pipeline Co

5

- 104 Tennessee Gas Pipeline Co

5

- 117 Tennessee Gas Pipeline Co

6

- 5 National Fuel Gas Supply Co

6

- 11 Dominion Trans (CNG)

6

- 11 Columbia Gas Trans Corp

6

- 19 Dominion Trans (CNG)

6

- 79 Texas Eastern Trans Corp

6

- 80 Dominion Trans (CNG)

6

- 80 Columbia Gas Trans Corp

6

- 118 Dominion Trans (CNG)

6

- 118 Tennessee Gas Pipeline Co

8

- 18 Southern Natural Gas Co

8

- 54 Transcontinental Gas Pipeline Co

8

- 95 Transcontinental Gas Pipeline Co

8

- 96 Southern Natural Gas Co

9

- 8 Southern Natural Gas Co

10

- 96 Florida Gas Trans Co

11

- 6 Texas Eastern Trans Corp

11

- 6 Tennessee Gas Pipeline Co

11

- 13 Dominion Trans (CNG)

11

- 18 Tennessee Gas Pipeline Co

11

- 80 Columbia Gas Trans Corp

12

- 11 Columbia Gas Trans Corp

12

- 17 ANR Pipeline Co

12

- 17 Panhandle Eastern Pipeline Co

12

- 98 ANR Pipeline Co

13

- 11 Dominion Trans (CNG)

13

- 11 Texas Eastern Trans Corp

13

- 14 Panhandle Eastern Pipeline Co

14

- 12 Panhandle Eastern Pipeline Co

14

- 12 ANR Pipeline Co

14

- 13 Texas Eastern Trans Corp

14

- 98 Trunkline Gas Co

15

- 14 Panhandle Eastern Pipeline Co

15

- 16 Nat Gas Pipeline Co of America

## 24 Link Pipeline

16

- 20 ANR Pipeline Co

16

- 98 ANR Pipeline Co

17

- 78 Great Lakes Gas Trans Ltd

17

- 98 Panhandle Eastern Pipeline Co

17

- 99 Michcon

18

- 8 East Tennessee Nat Gas Co

18

- 11 Texas Eastern Trans Corp

18

- 11 Tennessee Gas Pipeline Co

18

- 13 Columbia Gas Trans Corp

18

- 56 Tennessee Gas Pipeline Co

18

- 61 Columbia Gas Trans Corp

18

- 80 Columbia Gas Trans Corp

18

- 80 Tennessee Gas Pipeline Co

18

- 92 East Tennessee Nat Gas Co

18

- 116 Texas Eastern Trans Corp

19

- 79 Transcontinental Gas Pipeline Co

19

- 92 Columbia Gas Trans Corp

19

- 93 Dominion Trans (CNG)

21

- 15 Panhandle Eastern Pipeline Co

23

- 20 ANR Pipeline Co

23

- 22 Great Lakes Gas Trans Ltd

23

- 25 Great Lakes Gas Trans Ltd

23

- 99 Great Lakes Gas Trans Ltd

23

- 106 Great Lakes Gas Trans Ltd

24

- 16 Nat Gas Pipeline Co of America

25

- 23 Great Lakes Gas Trans Ltd

25

- 77 Great Lakes Gas Trans Ltd

26

- 24 Nat Gas Pipeline Co of America

27

- 24 Williston Basin Pipeline Co

27

- 41 Williston Basin Pipeline Co

28

- 15 Panhandle Eastern Pipeline Co

28

- 16 ANR Pipeline Co

28

- 21 Panhandle Eastern Pipeline Co

28

- 26 Nat Gas Pipeline Co of America

28

- 29 Colorado Interstate Gas

28

- 68 Colorado Interstate Gas

28

- 108 Nat Gas Pipeline Co of America

28

- 109 Southern Star Central (Williams)

29

- 31 Colorado Interstate Gas

30

- 31 Colorado Interstate Gas

30

- 48 Northwest Pipeline Corp

30

- 113 Northwest Pipeline Corp

31

- 28 Southern Star Central (Williams)

31

- 29 Colorado Interstate Gas

32

- 33 El Paso Nat Gas Co

## 25 Link Pipeline

32

- 33 Transwestern Pipeline Co

32

- 113 Northwest Pipeline Corp

33

- 63 El Paso Nat Gas Co

33

- 68 Transwestern Pipeline Co

33

- 97 El Paso Nat Gas Co

33

- 101 El Paso Nat Gas Co

33

- 101 Transwestern Pipeline Co

34

- 27 Williston Basin Pipeline Co

34

- 31 Wyoming Interstate Co

36

- 37 Socal Gas

36

- 103 Socal Gas

37

- 38 Pacific Gas & Electric

40

- 41 Northwest Energy

41

- 83 Williston Basin Pipeline Co

43

- 73 Terasen (BC Gas)

44

- 45 Northwest Pipeline Corp

45

- 46 Northwest Pipeline Corp

46

- 48 Northwest Pipeline Corp

48

- 47 Northwest Pipeline Corp

51

- 66 Texas Eastern Trans Corp

54

- 8 Transcontinental Gas Pipeline Co

54

- 8 Southern Natural Gas Co

55

- 114 Transcontinental Gas Pipeline Co

56

- 18 Tennessee Gas Pipeline Co

56

- 54 Transcontinental Gas Pipeline Co

56

- 54 Southern Natural Gas Co

56

- 58 Gulf South (Koch)

56

- 114 Gulf South (Koch)

57

- 58 Tennessee Gas Pipeline Co

57

- 58 Southern Natural Gas Co

57

- 58 Texas Eastern Trans Corp

58

- 56 Transcontinental Gas Pipeline Co

58

- 56 Southern Natural Gas Co

58

- 56 Tennessee Gas Pipeline Co

58

- 60 Transcontinental Gas Pipeline Co

58

- 60 Southern Natural Gas Co

58

- 60 Texas Eastern Trans Corp

58

- 60 Tennessee Gas Pipeline Co

58

- 60 Florida Gas Trans Co

58

- 114 Florida Gas Trans Co

58

- 114 Gulf South (Koch)

58

- 116 Texas Eastern Trans Corp

59

- 57 Tennessee Gas Pipeline Co

60

- 61 Trunkline Gas Co

60

- 61 Gulf South (Koch)

## 26 Link Pipeline

60

- 61 ANR Pipeline Co

60

- 61 Tennessee Gas Pipeline Co

60

- 65 Nat Gas Pipeline Co of America

61

- 18 Tennessee Gas Pipeline Co

61

- 56 Southern Natural Gas Co

61

- 115 ANR Pipeline Co

61

- 115 Trunkline Gas Co

61

- 116 Texas Eastern Trans Corp

62

- 60 Tennessee Gas Pipeline Co

62

- 60 ANR Pipeline Co

62

- 60 Trunkline Gas Co

62

- 60 Transcontinental Gas Pipeline Co

62

- 60 Texas Eastern Trans Corp

63

- 53 El Paso Nat Gas Co

63

- 64 Epgt Texas Pipeline (Valero)

63

- 64 Txu Lonestar Gas Pipeline

63

- 65 Oasis

63

- 66 Epgt Texas Pipeline (Valero)

63

- 68 Epgt Texas Pipeline (Valero)

63

- 68 Nat Gas Pipeline Co of America

63

- 97 El Paso Nat Gas Co

64

- 65 Txu Lonestar Gas Pipeline

64

- 108 Nat Gas Pipeline Co of America

65

- 60 Trunkline Gas Co

65

- 60 Transcontinental Gas Pipeline Co

65

- 60 Texas Eastern Trans Corp

65

- 61 Tennessee Gas Pipeline Co

65

- 107 Nat Gas Pipeline Co of America

66

- 51 Tennessee Gas Pipeline Co

66

- 65 Epgt Texas Pipeline (Valero)

66

- 65 Texas Eastern Trans Corp

66

- 65 Tennessee Gas Pipeline Co

66

- 65 Nat Gas Pipeline Co of America

66

- 65 Transcontinental Gas Pipeline Co

67

- 65 Nat Gas Pipeline Co of America

67

- 66 Transcontinental Gas Pipeline Co

68

- 28 Nat Gas Pipeline Co of America

68

- 108 Nat Gas Pipeline Co of America

77

- 25 Great Lakes Gas Trans Ltd

78

- 106 Union Gas

79

- 105 Texas Eastern Trans Corp

79

- 105 Transcontinental Gas Pipeline Co

80

- 11 Dominion Trans (CNG)

80

- 19 Columbia Gas Trans Corp

80

- 92 Columbia Gas Trans Corp

## 27 Link Pipeline

83

- 31 Colorado Interstate Gas

92

- 18 Dominion Trans (CNG)

92

- 93 Columbia Gas Trans Corp

94

- 19 Transcontinental Gas Pipeline Co

94

- 92 Transcontinental Gas Pipeline Co

94

- 93 Transcontinental Gas Pipeline Co

95

- 94 Transcontinental Gas Pipeline Co

97

- 52 El Paso Nat Gas Co

97

- 53 El Paso Nat Gas Co

97

- 102 El Paso Nat Gas Co

98

- 99 ANR Pipeline Co

99

- 17 Great Lakes Gas Trans Ltd

101

- 35 El Paso Nat Gas Co

101

- 36 Socal Gas

101

- 37 Pacific Gas & Electric

101

- 102 El Paso Nat Gas Co

102

- 36 Socal Gas

104

- 1 Iroquois Pipeline Co

104

- 3 Iroquois Pipeline Co

104

- 4 Tennessee Gas Pipeline Co

104

- 79 Columbia Gas Trans Corp

105

- 4 Transcontinental Gas Pipeline Co

105

- 4 Texas Eastern Trans Corp

105

- 104 Algonquin Gas Trans Co

106

- 5 Tennessee Gas Pipeline Co

107

- 15 Nat Gas Pipeline Co of America

107

- 61 Gulf South (Koch)

107

- 61 Centerpoint Energy (Reliant)

107

- 64 Txu Lonestar Gas Pipeline

107

- 111 Texas Eastern Trans Corp

108

- 28 ANR Pipeline Co

108

- 107 Nat Gas Pipeline Co of America

108

- 109 Nat Gas Pipeline Co of America

108

- 110 Centerpoint Energy (Reliant)

109

- 21 Southern Star Central (Williams)

110

- 107 Nat Gas Pipeline Co of America

110

- 109 Centerpoint Energy (Reliant)

110

- 111 Centerpoint Energy (Reliant)

111

- 112 Texas Eastern Trans Corp

111

- 115 Centerpoint Energy (Reliant)

112

- 15 Nat Gas Pipeline Co of America

113

- 30 Wyoming Interstate Co

114

- 54 Transcontinental Gas Pipeline Co

114

- 96 Florida Gas Trans Co

115

- 14 Trunkline Gas Co

## 28 Link Pipeline

115

- 14 ANR Pipeline Co

116

- 18 Texas Eastern Trans Corp

116

- 58 Texas Eastern Trans Corp

117

- 5 Dominion Trans (CNG)

117

- 104 Dominion Trans (CNG)

117

- 105 Transcontinental Gas Pipeline Co

117

- 118 Transcontinental Gas Pipeline Co

117

- 118 Dominion Trans (CNG)

117

- 118 Tennessee Gas Pipeline Co

117

- 118 National Fuel Gas Supply Co

118

- 5 National Fuel Gas Supply Co

## 29 Table 10

- 4 U.S. and Canada Natural Gas Resources and Reserves

Region Beginning of Year 2015

Undiscovered Dry Gas

Resource (Tcf) (1) Dry Gas Reserves (Tcf)

Lower 48 Onshore Non Associated 2,530 275

Conventional (includes tight) 516 86

Northeast 34 8

Gulf Coast 130 18

Midcontinent 89 15

Southwest 15 10

Rocky Mountain 236 35

West Coast 11 0

Shale Gas 1,964 180

Northeast 978 88

Gulf Coast 560 49

Midcontinent 137 19

Southwest 77 21

Rocky Mountain 196 4

West Coast 16 0

Coalbed Methane 50 9

Northeast 7 1

Gulf Coast 4 0

Midcontinent 7 1

Southwest

- -

Rocky Mountain 30 7

West Coast 1

-

Lower 48 Offshore Non Associated 118 13

Gulf of Mexico 117 13

Pacific 1 0

Atlantic

- -

Associated

- Dissolved Gas 122 11

Alaska 42 13

Total U.S. 2,811 312

Canada Non Associated 780 52

Conventional and Tight 79 30

Shale Gas 642 21

Coalbed Methane 60 2

Canada Associated

- Dissolved Gas 15 3

Total Canada 796 56

Total U.S and Canada 3,607 368

## 30 Table 10

- 5 Exploration and Development Assumptions

Region Fraction of

Hydrocarbons

that are Natual

Gas Liquids

(NGLs) Fraction of

Hydrocarbons

that are Crude

Oil Max Share of

Resources

that can be

Developed per

Year Exploration,

Development

Drilling

Required Lease

and Plant

Use

(Fraction) (Fraction) (Fraction) (Ft/Bcf) (Fraction)

(5) Niagara 0.254 0.023 0.06 10,000 0.06

(6) Leidy 0.147 0.824 0.06 4,086 0.03

(11) East Ohio 0.044 0.465 0.06 7,738 0.01

(12) Maumee/Defiance 0.088 0.331 0.06 10,000 0.01

(13) Lebanon 0.088 0.330 0.06 10,000 0.01

(14) Indiana 0.125 0.594 0.06 10,000 0.02

(15) South Illinois 0.131 0.621 0.06 10,000 0.36

(17) Southeast Michigan 0.126 0.595 0.06 10,000 0.05

(18) Tennessee/Kentucky 0.086 0.311 0.06 10,000 0.05

(21) Northern Missouri 0.008 0.920 0.06 10,000 0.05

(24) Ventura 0.008 0.920 0.06 10,000 0.34

(26) Nebraska 0.008 0.920 0.06 10,000 0.06

(28) Kansas 0.007 0.820 0.06 8,468 0.05

(29) East Colorado 0.164 0.798 0.06 9,846 0.06

(30) Opal 0.648 0.236 0.06 3,429 0.06

(31) Cheyenne 0.029 0.971 0.06 5,846 0.06

(32) San Juan Basin 0.066 0.085 0.06 5,549 0.15

(33) EPNG/TW 0.061 0.939 0.06 6,819 0.06

(34) North Wyoming 0.093 0.449 0.06 7,257 0.06

(35) South Nevada 0.353 0.291 0.06 8,085 0.06

(36) SOCAL Area 0.388 0.277 0.06 8,085 0.16

(37) Enhanced Oil Recovery Region 0.004 0.948 0.06 10,000 0.16

(38) PGE Area 0.342 0.272 0.06 8,085 0.16

(39) Pacific Offshore 0.026 0.785 0.06 2,500 0.16

(41) Montana/North Dakota 0.152 0.766 0.06 10,000 0.16

(45) Pacific Northwest 0.308 0.267 0.06 8,085 0.03

(49) Eastern Canada Offshore 0.084 0.111 0.06 10,000 0.07

(54) North Alabama 0.142 0.368 0.06 6,256 0.03

(55) Alabama Offshore 0.241 0.130 0.06 2,500 0.03

(56) North Mississippi 0.240 0.625 0.06 6,567 0.03

(57) East Louisiana Shelf 0.242 0.130 0.06 2,500 0.05

(58) Eastern Louisiana Hub 0.173 0.676 0.06 6,591 0.05

(59) Viosca Knoll/Desoto/Miss Canyon 0.000 1.000 0.06 2,500 0.05

(60) Henry Hub 0.259 0.709 0.06 6,591 0.05

(61) North Louisiana Hub 0.687 0.122 0.06 9,725 0.05

(62) Central and West Louisiana Shelf 0.241 0.130 0.06 2,500 0.05

(63) Southwest Texas 0.121 0.879 0.06 5,021 0.06

(64) Dallas/Ft Worth 0.623 0.300 0.06 5,464 0.06

(65) E. TX (Katy) 0.102 0.490 0.06 6,688 0.06

(66) S. TX 0.040 0.919 0.06 6,705 0.06

## 31 Region Fraction of

Hydrocarbons

that are Natual

Gas Liquids

(NGLs) Fraction of

Hydrocarbons

that are Crude

Oil Max Share of

Resources

that can be

Developed per

Year Exploration,

Development

Drilling

Required Lease

and Plant

Use

(Fraction) (Fraction) (Fraction) (Ft/Bcf) (Fraction)

(67) Offshore Texas 0.241 0.130 0.06 2,500 0.06

(68) NW TX 1.000 0.000 0.06 8,626 0.06

(69) Garden Banks 0.000 1.000 0.06 2,500 0.05

(70) Green Canyon 0.000 1.000 0.06 2,500 0.05

(71) Eastern Gulf 0.000 1.000 0.06 2,500 0.05

(72) North British Columbia 0.969 0.013 0.06 10,000 0.10

(74) Caroline 0.011 0.765 0.06 9,651 0.12

(76) Saskatchewan 0.012 0.366 0.06 10,000 0.09

(78) Dawn 0.072 0.111 0.06 10,000 0.09

(80) West Virginia 0.151 0.804 0.06 3,642 0.05

(83) Wind River Basin 0.007 0.630 0.06 5,297 0.06

(87) South Alaska 0.000 0.000 0.06 10,000 0.08

(89) North Alaska 0.000 0.000 0.06 10,000 0.99

(92) Southwest VA 0.044 0.162 0.06 7,665 0.03

(96) North Florida 0.208 0.540 0.06 6,567 0.26

(98) Southwest Michigan 0.126 0.595 0.06 10,000 0.05

(99) Northern Michigan 0.337 0.502 0.06 8,950 0.05

(107) Carthage 0.387 0.000 0.06 2,872 0.06

(108) Southwest Oklahoma 0.014 0.557 0.06 7,953 0.05

(109) Northeast Oklahoma 0.003 0.950 0.06 8,776 0.05

(110) Southeastern Oklahoma 0.037 0.679 0.06 4,502 0.05

(111) Northern Arkansas 0.820 0.166 0.06 3,996 0.05

(112) Southeast Missouri 0.007 0.885 0.06 10,000 0.05

(113) Uinta/Piceance 0.381 0.001 0.06 8,839 0.06

(114) South MS/AL 0.235 0.612 0.06 6,567 0.03

(115) West KY/TN 0.121 0.572 0.06 10,000 0.05

(117) Northeast PA 0.712 0.284 0.06 3,331 0.05

(118) Leidy 0.130 0.861 0.06 3,935 0.05

## 32 Figure 10

- 7 Resource Cost Curves at the Beginning of Year 2015

## 33 Figure 10

- 10 Incremental E&D Cost (BOY 2015) by Percentage of Dry Gas Resource Found

## 34 Figure 10

- 12 North American LNG Supply Curves

## 35 Figure 10

- 13 North American LNG Regasification Facilities Map

Figure 10

- 14 Examples of Firm Demand Curves by Electric Load Segment Existing

Potential Under Construction (1) Cove Point

(2) Elba Island (3) Everett

(14) NE Gateway

(4) Gulf Gateway (5) Lake Charles

(6) Altamira (7) Costa Azul (8) Cameron LNG

(10) Golden Pass

(9) Freeport LNG (11) Canaport

(12) Sabine Pass

(13) Gulf LNG Energy

(15) Manzanillo

## 36 Figure 10

- 15 Examples of Interruptible Demand Curves by Electric Load Segment

Figure 10

- 16 LNG Export Assumptions in EPA Base Case v.5.15

## 37 Figure 10

- 17 New England Pipeline Corridors in 2020

## 38 Figure 10

- 18 Example Pipeline Discount Curve

## 39 Figure 10

- 22 Crude Oil and NGL Prices

## 40 Table 3

- 13 State Power Regulations in EPA Base Case v.5.15

State/Region Bill Emission

Type Emission Specifications Implementation

Status Notes

Alabama Alabama

Administrative

Code Chapter 335

-

3

- 8 NO

x 0.02 lbs/MMBtu for combined cycle EGUs which commenced operation after April

1, 2003; For combined

- cycle electric generating units fired by natural gas: 4.0

ppmvd at 15% O2 (0.0178 lbs/MMBtu), by fuel oil

- 15.0 ppmvd at 15% O2

(0.0667 lbs/MMBtu) 2003

Arizona Title 18, Chapter 2,

Article 7 Hg 90% removal of Hg content of fuel or 0.0087 lbs/GWh annual reduction for all

non

- cogen coal units > 25 MW 2017

California CA Reclaim Market NO

x 9.68 MTons annual cap for list of entities in Appendix A of "Annual RECLAIM

Audit Market Report for the Compliance Year 2005" (304 entities)

1994 Since the Reclaim Trading Credits are

applicable to entities besides power plants,

we approximate by hardwiring the NO

x and

SO 2 allowance prices for the calendar year

2006. SO 2 2.839 MTons in 2016, 2.474 in 2018, and 2.219 in 2020 onward annual cap for

list of entities in Appendix A of "Annual RECLAIM Audit Market Report for the

Compliance Year 2005" (304 entities)

CA AB 32 CO 2 Power sector and Non

- power Sector Cap in Millio n metric tons. 2012 Refer to Section 3.9.4 for details

Colorado 40 C.F.R. Part 60 Hg 2012 & 2013: 80% reduction of Hg content of fuel or 0.0174 lbs/GWh annual

reduction for Pawnee Station 1 and Rawhide Station 101.

2014 through 2016: 80% reduction of Hg content of fuel or 0.0174 lbs/GWh

annual reduction for all coal units > 25 MW

2017 onwards: 90% reduction of Hg content of fuel or 0.0087 lb/GWh annual

reduction for all coal units > 25 MW 2012

Clean Air, Clean

Jobs Act NO

x, SO 2

, Hg Retire Arapahoe 3 by 2014; Cherokee 1 & 2 by 2012, Cherokee 3 by 2017;

Cameo 1 & 2; Valmont 5 by 2018; W N Clark 55 & 59 by 2015

Convert following units to natural gas: Arapahoe 4 by 2015; Cherokee 4 by 2018

Install SCRs in Hayden 1 & 2 by 2016; SCR + FGD in Pawnee 1 [al ready

installed] 2010

Hg Comanche Units 1, 2, and 3 together limit of 0.000013 lbs/MWh 2012

NO

x Craig Station Unit 1 and Unit 3 NO

x Limit 0.28lbs/MMBtu 2012

NO

x Craig Station Unit 2 NO

x Limit 0.08 lbs/MMBtu 2012

Connecticut Executive Order 19

and Regulations of

Connecticut State

Agencies (RCSA)

22a

- 174

- 22 NO

x 0.15 lbs/MMBtu annual rate limit for all fossil units > 15 MW (Non

- ozone season

only)

2003 Executive Order

19, RCSA 22a

- 198

& Connecticut

General Statues

(CGS) 22a

- 198 SO 2 0.33 lbs/MMBtu annual rate limit for all fossil units > 25 MW (Title IV Sources)

0.55 lbs/MMBtu annual rate limit for all non

- fossil units > 15 MW and fossil units

< 25MW and > 15MW (Non

- Title IV Sources)

CGS section 22a

199 Hg 90% removal of Hg con tent of fuel or 0.0087 lbs/GWh annual reduction for all

coal

- fired units 2008

Delaware Regulation 1148:

Control of

Stationary

Combustion

Turbine EGU

Emissions NO

x 0.19 lbs/MMBtu ozone season PPMDV for stationary, liquid fuel fired CT EGUs

>1 MW

0.39 lbs/MMBtu ozone season PPMDV for stationary, gas fuel fired CT EGUs >1

MW 2009

## 41 State/Region Bill Emission

Type Emission Specifications Implementation

Status Notes

Regulation No.

1146: Electric

Generating Unit

(EGU) Multi

Pollutant

Regulation NO

x 0.125 lbs/MMBtu rate limit of NO

x annually for all coal and residual

- oil fired units >

25 MW 2009 The following units have specific NO

x , SO 2

, and Hg annual caps in MTons:

Edge Moor 3: 0.773 NO

x , 1.391 SO 2 , & 2012:

0.0000083 Hg, 2013 onwards: 0.0000033 Hg

Edge Moor 4: 1.339 NO

x , 2.41 SO 2 , & 2012:

0.0000144 Hg, 2013 onwards: 0.0000057 Hg

Edge Mo re 5: 1.348 NO

x & 2.427 SO 2

Indian River 3: 0.977 NO

x , 1.759 SO 2 , &

2012: 0.0000105 Hg, 2013 onwards:

0.0000042 Hg

Indian River 4: 2.032 NO

x , 3.657 SO 2 , &

2012: 0.0000219 Hg, 2013 onwards:

0.0000087 Hg

McKee Run 3 0.244 NO

x & 0.439 SO 2 SO 2 0.26 lbs/MMBtu annual rate limit for coal and residual

- oil fired units > 25 MW

Hg 2012: 80% removal of Hg content of fuel or 0.0174 lbs/GWh annual reduction for

all coal units > 25 MW

2013 onwards: 90% removal of Hg content of fuel or 0.0087 lbs/GWh annual

reduction for all coal units > 25 MW 2012

Regulation 1108:

Distillate Fuel Oil

rule SO 2 Any relevant units are to use 0.3% sulfur distillate fuel oil Fuel rule modeled through unit emission rates

Georgia Multi

- pollutant

Control for Electric

Utility Steam

Generating Units SCR,

FGD, and

Sorbent

Injection

Baghouse

controls to

be

installed The following plants must install controls: Bowen, Branch, Hammond,

McDonough, Scherer, Wansley, and Yates Implementation

from 2008

through 2015,

depending on

plant an d control

type

Illinois Title 35, Section

217.706 NO

x 0.25 lbs/MMBtu summer season rate limit for all fossil units > 25 MW 2003

Title 35, Part 225,

Subpart B 225.230 Hg 90% removal of Hg content of fuel; or a standard of .0080 lb Hg/GWh for sources

at or above 25 MW; If facility commenced operation on or before December 31,

2008, start date for implementation must be July 1, 2009 2009 Not Ameren Specific

Title 35 Part 225

Subpart B 225.233 NO

x 0.11 lbs/MMBtu annual rate limit and ozone season rate limit for all coal steam

units > 25 MW 2012

Not Ameren Specific SO 2 2015 onwards: 0.25 lbs/MMBtu annual rate limit for all coal steam units > 25 MW

or a rate equivalent to 35% of the base SO 2 emissions (whichever is more

stringent) 2015

Hg 90% removal of Hg content of fuel or 0.08 lbs/GWh annual reduction for all coal

units > 25 MW 2015

Title 35 Part 225

Subpart B 225.233

(MPS Ameren

specific) NOx 0.11 lbs/MMBtu annual rate limit and ozone season rate limit Ameren coal steam

units > 25 MW 2012

SO 2 2015 & 2016 onwards: 0.25 lbs/MMBtu annual rate limit for all Ameren coal

steam units > 25 MW

2017 onwards: 0.23 lbs/MMBtu annual rate limit for all Ameren coal steam units >

25 MW 2015

Title 35 Part 225;

Subpart F:

Combined

Pollutant

Standards

(REPEALED) NO

x 0.11 lbs/MMBtu ozone season and annual rate limit for all specified Midwest Gen

coal steam units 2012

REPEALED SO 2 0.44 lbs/MMBtu annual rate limit in 2013, decreasing annually to 0.11 lbs/MMBtu

in 2019 for all specified Midwest Gen coal steam units 2013

Hg 90% removal of Hg content of fuel or 0.08 lbs/GWh annual reduction for all

specified Midwest Gen coal steam units 2015

## 42 State/Region Bill Emission

Type Emission Specifications Implementation

Status Notes

Kansas NO

x Emission

Reduction Rule,

K.A.R. 28

- 19

- 713a.

(Nearman Unit 1) NO

x Annual rate limit .26 lbs/MMBtu 2012

N O

x Emission

Reduction Rule,

K.A.R. 28

- 19

- 713a.

(Quindaro Unit 2) NO

x Annual rate limit .20 lbs/MMBtu 2012

Louisiana Title 33 Part IIl

- Chapter 22,

Control of Nitrogen

Oxides NO

x For units >/= 80 MMBtu/hr, rate limit in lbs/MMBtu:

Coal fired : 0.21

Oil

- fired: 0.18

All others (gas or liquid): 0.1

Stationary Sources >/= 10 MMBtu/hr, rate limit in lbs/MMBtu:

Oil

- fired: 0.3

Gas

- fired: 0.2 2005 Applicable for all units in Baton Rouge

Nonattainment Area & Region of Influence.

Willow Glenn, located in Iberville, obtained a

permit that allows its gas

- fired units to

maintain a cap. These units are separately

modeled.

Title 33, Part III

-

Chapter 15,

Emission

Standards for

Sulfur Dioxide SO 2 1.2 lbs/MMBtu ozone season ppmvd for all single point sources that emit or have

the potential to emit 5 tons or more of SO 2 2005

Maine Chapter 145 NO

x Control Program NO

x 0.22 lbs/MMBtu annual rate limit for all fossil fuel units > 25 MW built before 1995

with a heat input capacity < 750 MMBtu/hr.

0.15 lbs/MMBtu annual rate limit for all fossil fuel units > 25 MW built before 1995

with a heat input capacity > 750 MMBtu/hr.

0.20 lbs/MMBtu annual rate limit for all fossil fuel fired indirect heat exchangers,

primary boilers, and resource rec overy units with heat input capacity > 250

MMBtu/hr 2005

38 MRSA Section

603

- A Low Sulfur

in Fuel Rule SO 2 All fossil units require the use of 0.5% sulfur residual oil [0.52 lbs/MMBtu] 2018 Fuel rule modeled through unit emission rates

Statue 585

- B Title

38, Chapter 4:

Protection and

Improvement of Air Hg 25 lbs annual cap for any facility including EGUs (0.0000125 MTons) 2010

Maryland Maryland Healthy

Air Act NO

x 7.3 MTons summer cap and 16.7 MTons annual cap for 15 specific existing coal

steam units

2009 SO 2 2009 through 2012: 48.6 MTons annual cap for 15 specific existing coal steam

units

2013 onwards: 37.2 MTons annual cap for 15 specific existing coal steam units

Hg 2010 through 2012: 80% removal of Hg content of fuel for 15 specific existing

coal steam units

2013 onwards: 90% removal of Hg content of fuel for 15 specific existing coal

steam units

Massachusetts 310 CMR 7.29 NO

x 1.5 lbs/MWh annual GPS for Brayton Point, Mystic Generating Station, Mount

Tom, Canal, and Salem Harbor

2006

SO 2 3.0 lbs/MWh annual GPS for Brayton Point, Mystic Generating Station, Mount

Tom, Canal, and Salem Harbor

## 43 State/Region Bill Emission

Type Emission Specifications Implementation

Status Notes

Hg 2012: 85% removal of Hg content of fuel or 0.0000025 lbs/MWh annual GPS for

Brayton Point, Mystic Generating Station, Mount Tom, Canal, and Salem Harbor

2013 onwards: 95% removal of Hg content of fuel or 0.0000025 lbs/MWh annual

GPS for Brayton Point, My stic Generating Station, Mount Tom, Canal, and Salem

Harbor Brayton units 1 through 3 have an annual Hg

cap of 0.0000733 MTons

Mt. Tom 1 has an annual Hg cap of

0.00000205 MTons

Salem Harbor units 1 through 3 have an

annual Hg cap of 0.0000106 MTons

310 CMR 7.04 SO 2 Sulfur in Fuel Oil Rule requires the use of 0.5% sulfur residual oil [0.52

lbs/MMBtu] by July 1, 2014 for units greater than 250 MMBtu energy input; by

July 1, 2018 for all residual oil units except for those located in the Berkshire

APCD. 20 14 Fuel rule modeled through unit emission rates

Michigan Part 18 Rules

– R

336.1801 (2) (a) NO

x For all fossil units > 25 MW, and annual PTE of NO

x >25 tons,.25 lbs/MMBtu

ozone season rate, OR 65% NO

x reductions from 1990 levels 2004

Part 18 Rules

– R

336.1801 (2) (a) SO 2 SO 2 ppmvd rates in 50% excess air for units in Wayne county: Pulverized coal:

550;Other coal: 420;Distillate oil Nos. 1 & 2: 120;Used oil: 300;Crude and Heavy

oil: 400

2012 Not modeled in IPM as limits are within SIP

rates For all other units,

with 0

- 500,000 lbs Steam per Hour Plant Capacity: 2.5

with >500,000 lbs Steam per Hour Plant Capacity: 1.67

Part 15. Emission

Limitations and

Prohibitions

-

Mercury Hg 90% removal of Hg content of fuel annually for all coal units > 25 MW 2015

Minnesota Minnesota Hg

Emission

Reduction Act Hg 90% removal of Hg content of fuel annually for all coal facilities > 500 MW

combined; Dry scrubbed units must implement by December 31, 2010; Wet

scrubbed units must implement by December 31, 2014. 2006

Missouri 10 CSR 10

- 6.350 NO

x 0.25 lbs/MMBtu annual rate limit for all fossil fuel units > 25 MW in the following

counties: Bollinger, Butler, Cape Girardeau, Carter, Clark, Crawford, Dent,

Dunklin, Gasconade, Iron, Lewis, Lincoln, Madison, Marion, Mississippi,

Montgomery, New Madrid, Oregon, Pemiscot, Perry, Phelps, Pike, Ralls,

Reynolds, Ripley, St. Charles, St. Fra ncois, Ste. Genevieve, Scott, Shannon,

Stoddard, Warren, Washington and Wayne

0.18 lbs/MMBtu annual rate limit for all fossil fuel units > 25 MW the following

counties: City of St. Louis, Franklin, Jefferson, and St. Louis

0.35 lbs/MMBtu annual rate limit for all fossil fuel units > 25 MW in the following

counties: Buchanan, Jackson, Jasper, Randolph, and any other county not listed 2004

Montana Montana Mercury

Rule Adopted

10/16/06 Hg 0.90 lbs/TBtu annual rate limit for all non

- lignite coal units

1.50 lbs/TBtu annual rate limit for all lignite coal units 2010

New

Hampshire RSA 125

- O: 11

- 18 Hg 80% reduction of aggregated Hg content of the coal burned at the facilities for

Merrimack Units 1 & 2 and Schiller Units 4, 5, & 6 2012

ENV

- A2900

Multiple pollutant

annual budget

trading and

banking program NO

x 2.90 MTons summer cap for all fossil steam units > 250 MMBtu/hr operated at

any time in 1990 and all new units > 15 MW

3.64 MTons annual cap for Merrimack 1 & 2, Newington 1, and Schiller 4 through

6 2007

SO 2 7.29 MTons annual cap for Merrimack 1 & 2, Newington 1, and Schiller 4 through

6

Env

- A 2300

- Mitigation of

Regional Haze SO 2 90% SO 2 control at Merrimack 1 & 2; 0.5 lb SO 2 /MMBtu 30 day rolling average at

Newington 1

2013

NO

x 0.30 lb NO

x /MMBtu 30

- day rolling average at Merrimack 2; 0.35 lb NO

x /MMBtu

when burning oil and 0.25 lb NO

x /MMBtu when burning oil and gas at Newington

1(permit condition).

## 44 State/Region Bill Emission

Type Emission Specifications Implementation

Status Notes

New Jersey N.J. A. C. Title 7,

Chapter 27,

Subchapter 10.2 SO 2 0.15 (30 day rolling average) lbs/MMBtu 2012

N.J.A.C. 7:27

- 27.5,

27.6, 27.7, and

27.8 Hg 90% removal of Hg content of fuel annually for all coal

- fired units or <= 3.0

mg/MWh (net)

95% removal of Hg content of fuel annually for all MSW incinerator units or <= 28

ug/dscm 2007

N.J. A. C. Title 7,

Chapter 27,

Subchapter 19,

Table 1 NO

x Annual rate limits in lbs/MMBtu for the following technologies:

1.0 for tangential and wall

- fired wet

- bottom coal boilers serving an EGU

0.60 for cyclone

- fired wet

- bottom coal boilers serving an EGU 2007 No longer operative. Operative through

December 14, 2012

N.J. A. C. Title 7,

Chapter 27,

Subchapter 19,

Table 2 NO

x Annual rate limits in lbs/MMBtu for the following technologies:

0.38 for tangential dry

- bottom coal boilers serving an EGU

0.45 for wall

- fired dry

- bottom coal boilers serving an EGU

0.55 for cyclone

- fired dry

- bottom coal boilers serving an EGU

Li m its in l b s /MWh

1.50 for tangential, wall

- fired, and cyclone

- fired coal boilers serving an EGU

2.00 for tangential oil and/or gas boilers serving an EGU

2.80 for wall fired oil and/or gas boilers serving an EGU

4.30 for cyclone

- fired oil and/or gas boilers serving an EGU

2.00 for tangential and wall fired gas only boilers serving an EGU

4.30 for cyclone fired gas only boilers serving an EGU Operative from

December 15,

2012 through

April 30, 2015

N.J. A. C. Title 7,

Chapter 27,

Subchapter 19,

Table 3 NO

x Annual rate limit lbs/MWh

- 1.50 for coal fired boilers serving an EGU; 2.00 for

heavier than No.2 fuel oil fired boilers serving an EGU; 1.00 for No.2 and lighter

fuel oil fired and gas only fired boilers serving an EGU 05/01/2015

N.J. A. C. Title 7,

Chapter 27,

Subchapter 19,

Table 6; non

- High

Electricity demand

Day (HEDD) unit NO

x 2.2 lbs/MWh for gas

- burning simple cycle combustion turbine units

3.0 lbs/MWh for oil

- burning simple cycle combustion turbine units

1.3 lbs/MWh for gas

- burning combined cycle CT or regenerative cycle CT units

2.0 lbs/MWh for oil

- burning combined cycle CT or regenerative cycle CT uni ts 05/20/2009

N.J. A. C. Title 7,

Chapter 27,

Subchapter 19,

Table 7; High

Electricity demand

Day (HEDD) unit NO

x 1.0 lbs/MWh for gas

- burning simple cycle combustion turbine units

1.6 lbs/MWh for oil

- burning simple cycle combustion turbine units

0.75 lbs/MWh for gas

- burning combined cycle CT or regenerative cycle CT units

1.2 lbs/MWh for oil

- burning combined cycle CT or regenerative cycle CT units 2007 On and after May 1, 2015, the owner or

operator of a stationary combustion turbine

that is a HEDD uni t or a stationary

combustion turbine that is capable of

generating 15 MW or more and that

commenced operation on or after May 1,

2005 shall comply with limits outlines “in

Table 7 during operation on high electricity

demand days, regardless of the fuel

com busted, unless combusting gaseous fuel

is not possible due to gas curtailment."

New York Part 237 NO

x 39.91 Mtons [Thousand tons] non

- ozone season cap for fossil fuel units > 25 MW 2004 Repealed

Part 238 SO 2 131.36 MTons [Thousand tons] annual cap for fossil fuel units > 25 MW 2005 Repealed

## 45 State/Region Bill Emission

Type Emission Specifications Implementation

Status Notes

Mercury Reduction

Program for Coal

Fired Electric Utility

Steam Generating

Units Hg 786 lbs annual cap through 2014 for all coal fired boiler or CT units >25 MW after

Nov. 15, 1990. For facilities identified in Table 1 of Part 246 and includes 40 lbs set

aside

.

0.60 lbs/TBtu annual rate limit for all coal units > 25 MW developed after Nov.15

1990 for new units and existing facilities

– effective Jan 1, 2015. 2010

Subpart 227

- 2

Reasonably

Available Control

Technology

(RACT) For Major

Facilities of Oxides

Of Nitrogen (NO

x ) NO

x Annual rate in lbs/MMBTu for very large boilers >250 MMBtu/hr on or after July 1,

2014;

Gas only, tangential & wall fired : 0.08

Gas/oil tangential & wall fired : 0.15; cyclone: 0.2

Coal Wet Bottom, tangential & wall fired : 0.12; cyclone: 0.2

Coal Dry Bottom, tangential & wall fired : 0.12; stokers: 0.08

2004 Annual rate in lbs/MMBTu for large boilers between 100 and 250 MMBtu/hr on or

after July 1, 2014;

Gas Only: 0.06

Gas/Oil: 0.15

Pulverized Coal: 0.20

Coal (Overfeed Stoker/FBC): 0.8

Annual rate in lbs/MMBTu for mid

- size boilers between 25 and 100 MMBtu/hr on

or after July 1, 2014;

Gas Only: 0.05

Distillate Oil/Gas: 0.08

Residual Oil/Gas: 0.20

CTs operating after July 1, 2014 must submit a RACT determination to NYSDEC Compliance with these emission limits must

be determined with a one hour average

during the ozone season and a 30

- day

average during the non

- ozone season unless

the owner or operator chooses to use a

CEMS under the provisions of section 227

- 2.6(b) of this Subpart.

## 46 State/Region Bill Emission

Type Emission Specifications Implementation

Status Notes

Stationary internal combustion engines having a maximum mechanical output

=> 200 brake horsepower in a severe ozone nonattainment area or having a

maximum mechanical output rating =>400 brake horsepower outside a severe

ozone nonattainment

area must comply with one of the emission limits in paragraph (1), (2), or (3) of

this sub division or a case

- by

- case RACT determination made pursuant to

paragraph (4) of this subdivision, as applicable:

(1) For internal combustion engines fired solely with natural gas: 1.5 grams per

brake horsepower

- hour.

(2) For internal combustion engines fir ed with landfill gas or digester gas (solely

or in combination with natural gas): 2.0 grams per brake horsepower

- hour.

(3) For internal combustion engine fired with distillate oil (solely or in combination

with other fuels): 2.3 grams per brake horsepower

- hour.

(4) For stationary internal combustion engines fired primarily with fuels not listed

above, the owner or operator must submit a proposal for RACT to be

implemented that includes descriptions of:

(i) the available NO

x control technologies, the project ed effectiveness of the

technologies considered, and the costs for installation and operation for each of

the technologies; and(ii) the technology and the appropriate emission limit

selected as RACT considering the costs for installation and operation of t he

technology.

(5) Any stationary internal combustion engine may rely on an emission limit that

reflects a 90 percent or greater NO

x reduction from the engine's actual 1990

baseline emissions, if such emissions baseline exists.

(6) Emergency power generati ng stationary internal combustion engines, and

engine test cells at engine manufacturing facilities that are used for either

research and development purposes, reliability testing, or quality assurance

performance testing are exempt from the requirements o f this subdivision.

Part 251 CO 2

Performance

Standards for Major

Electric Generating

Facilities CO 2 1450 lbs/MWh rate limit for New Combustion Turbines =>25MW

925 lbs/MWh rate limit for New Fossil Fuel except CT =>25MW 2012

North Carolina NC Clean

Smokestacks Act:

Statute 143

-

215.107D NO

x 25 MTons annual cap for Progress Energy coal plants > 25 MW and 31 MTons

annual cap for Duke Energy coal plants > 25 MW 2007

SO 2 2012: 100 MTons annual cap for Progress Energy coal plants > 25 MW and 150

MTons annual cap for Duke Energy coal plants > 25 MW

2013 onwards: 50 MTons annual cap for Progress Energy coal plants > 25 MW

and 80 MTons annual cap for Duke Energy coal plants > 25 MW 2009

SECTION .2500

– Mercury Rules for

Electric Generators Hg Coal

- fired electric steam >25 MW to comply with the mercury emission caps of

1.133 tons (36,256 ounces) per year between 2010 and 2017

inclusive and 0.447 tons (14,304 ounces) per year for 2018 and thereafter 2010 Vacated

15A NCAC 02D

.2511 Hg Duke Energy and Progress Energy Hg control plans submitted on January 1,

2013 and are awaiting approval. All control technologies and limitations must be

implemented by December 31, 2017. 2017

Oregon Oregon

Administrative

Rules, Chapter

345, Division 24 CO 2 675 lbs/MWh annual rate limit for new combustion turbines burning natural gas

with a CF >75% and all new non

- base load plants (with a CE <= 75%) emitting

CO 2 1997

## 47 State/Region Bill Emission

Type Emission Specifications Implementation

Status Notes

Oregon Utility

Mercury Rule

- Existing Units Hg 90% removal of Hg content of fuel reduction or 0.6 lbs/TBtu limitation for all

existing coal units >25 MW 2012

Oregon Utility

Mercury Rule

-

Potential Units Hg 25 lbs limit for all potential coal units > 25 MW 2009

Texas Senate Bill 7

Chapter 101 SO 2 273.95 MTons cap of SO 2 for all grandfathered units built before 1971 in East

Texas Region

2003

NO

x Annual cap for all grandfathered units built before 1971 in MTons: 84.48 in East

Texas, 18.10 in West Texas, 1.06 in El Paso Region

Chapter 117 NO

x East and Central Texas annual rate limits in lbs/MMBtu for units that came online

before 1996:

Gas fired units: 0.14

Coal fired units: 0.165

Stationary gas turbines: 0.14

2007 Units are also allowed to comply by reducing

the same amount of NO

x on a monthly basis

using a system cap or by purchasing credits.

East and Central Texas, Dallas/Fort Worth

Area, Beaumont

- Port Arthur region units are

assumed to be in compliance based on their

reported 2011 ETS r ates. The regulations for

these regions are not modeled. Dallas/Fort Worth Area annual rate limit for utility boilers, auxiliary steam boilers,

stationary gas turbines, and duct burners used in an electric power generating

system except for CT and CC units online after 1992:

0.033 lbs/MMBtu or 0.50 lbs/MWh output or 0.0033 lbs/MMBtu on system wide

heat input weighted average for large utility systems

0.06 lbs/MMBtu for small utility systems

Houston/Galveston region annual Cap and Trade (MECT) for all fossil units:

17.57 MTons

Beaumont

- Port Arthur region annual rate limits for utility boilers, auxiliary steam

boilers, stationary gas turbines, and duct burners used in an electric power

generating system: 0.10 lbs/MMBtu

Utah R307

- 424 Permits:

Mercury

Requirements for

Electric Generating

Units Hg 90% removal of Hg content of fuel annually or .65 lbs/MMbtu for all coal units >

25 MW 2013

Washington Washington State

House Bill 3141 CO 2 $1.45/MTons cost (2004$) for all new fossil

- fuel power plant 2004

Washington State

House Bill 5769 CO 2 1100 lbs/MWh rate limit for new coal plants 2011

Wisconsin NR 428 Wisconsin

Administration

Code NO

x Annual rate limits in lbs/MMBtu for coal fired boilers > 1,000 MMBtu/hr :

Wall fired, tangential fired, cyclone fired, and fluidized bed: 2013 onwards: 0.10

Arch fired: 2009 onwards: 0.18

2009 Annual rate limits in lbs/MMBtu for coal fired boilers between 500 and 1,000

MMBtu/hr:

Wall

- fired with a heat release rate=> 17,000 Btu per cubic feet per hour; 2013

onwards: 0.17 ; if heat input is lesser:

Tangential fired: 2009 onwards: 0.15

Cyclone fired: 2013 onwards: 0.15

Fluidized bed: 2013 onwards: 0.10

Arch fired: 2009 onwards: 0 .18

Annual rate limits in lbs/MMBtu for coal fired boilers between 250 and 500

MMBtu/hr:

Same as for coal boiled between 500 and 1000 MMBtu/hr in addition to:

Stoker Fired: .20

## 48 State/Region Bill Emission

Type Emission Specifications Implementation

Status Notes

Annual rate limits in lbs/MMBtu for coal fired boilers between 50 and 250

MMBtu/hr:

Same as for coal boiled between 500 and 1000 MMBtu/hr in addition to:

Stoker Fired: .25

Annual rate limits for CTs in lbs/MMBtu:

Natural gas CTs > 50 MW: 0.11

Distillate oil CTs > 50 MW: 0.28

Biologically derived fuel CTs > 50 MW: 0.15

Natural gas CTs between 25 and 49 MW: 0.19

Distillate oil CTs between 25 and 49 MW: 0.41

Biologically derived fuel CTs between 25 and 49 MW: 0.15

Annual rate limits for CCs in lbs/MMBtu:

Natural gas CCs > 25 MW: 0.04

Distillate oil CCs > 25 MW: 0.18

Biologically derived fuel CCs > 25 MWs: 0.15

Natural gas CCs between 10 and 24 MW: 0.19

Chapter NR

44.12/446.13

Control of Mercury

Emissions Hg Large (150MW capacity or greater) or small (between 25 and 150 MW) coal

- fired

EGU, 2015 onwards: 90% removal of Hg content of fuel or 0.0080 lbs/GWh

reduction in coal fired EGUs > 150 MW 2015

Chapter NR 446.14

Multi

- pollutant

reduction

alternative for coal

fired electrical

generating units Hg All Coal>25MW;

70% reduction in fuel, or .0190 lbs per GW

- hr from CY 2015

– CY 2017

(0.00005568 lbs/MMBtu)

80% reduction in fuel, or .0130 lbs per GW

- hr from CY2018

– CY 2020

(0.0000381 lbs/MMBtu)

90% reduction in fuel, or .0080 lbs pe r GW

- hr from January 1, 2021 onwards

(0.00000234 lbs/MMBtu) 2015 Alternative already modeled in IPM

SO 2 All Coal>25MW; .10 lbs per mmBTU by January 1, 2015

NO

x All Coal>25MW; 0.07 lbs per mmBTU by January 1, 2015

## 49 Table 3

- 14 New Source Review (NSR) Settlements in EPA Base Case v

. 5.1 5

Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Alabama Power

James H.

Miller Alabama Unit 3 Install and

operate FGD

continuously 95% 12/31/11 Operate existing

SCR continuously 0.1 05/01/08 0.03 12/31/06

Within 45 days of

settlement entry,

APC must retire

7,538 SO 2 emission

allowances. APC shall not sell,

trade, or otherwise

exchange any Plant

Miller excess SO 2

emission allowances

outside of the APC

system 1/1/21 1) Settlement requires 95%

remov al efficiency for SO 2 or 90%

in the event that the unit combust a

coal with sulfur content greater

than 1% by weight. 2) The

settlements require APC to retire

$4,900,000 of SO 2 emission

allowances within 45 days of

consent decree entry. 3) EPA

assumed a retirement of 7, 538

SO 2 allowances based on a

current allowance price of $650. http://www2.e

pa.gov/enforc

ement/alabam

a

- power

company

clean

- air

- act

settlement Alabama Unit 4 Install and

operate FGD

continuously 95% 12/31/11 Operate existing

SCR continuously 0.1 05/01/08 0.03 12/31/06 1/1/21

Minnkota Power Cooperative

Beginning 1/01/2006, Minnkota shall not emit more than 31,000 tons of SO 2 /year, no more than 26,000 tons beginning 2011, no more than 11,500 tons beginning 1/01/2012. If Unit 3 is not operational by

12/31/2015, then beginning 1/01/2014, the plant wide emission shall not exceed 8,500.

Milton R.

Young North

Dakota Unit 1 Install and

continuously

operate FGD 95% if wet

FGD, 90% if

dry 12/31/11 Install and

continuously

operate Over

- fire

AIR, or equivalent

technology with

emission rate <

.36 0.36 12/31/09 0.03 if wet

FGD, .015

if dry FGD Plant will surrender

4,346 allowances for

each year 2012

–

2015, 8,693

allowances for years

2016

– 2018, 12,170

allowances for year

2019, and 14,886

allowances/year

thereafter if Units 1

– 3 are operational by

12/31/2015. If only

Units 1 and 2 are

operati onal

by12/31/2015, the

plant shall retire

17,886 units in 2020

and thereafter. Minnkota shall not sell

or trade NO

x allowances allocated

to Units 1, 2, or 3 that

would otherwise be

available for sale or

trade as a result of the

actions taken by the

settli ng defendants to

comply with the

requirements 1) Settlement requires 95%

removal efficiency for SO 2 at Unit 1

if a wet FGD is installed, or 90% if

a dry FGD is installed. The FGD

for Units 1 and 2 and the NO

x control for Unit 1 are modeled as

emission c onstraints in EPA Base

Case, the NO

x control for Unit 2 is

hardwired into EPA Base Case. 2)

Beginning 12/31/2010, Unit 2 will

achieve a phase II average NO

x emission rate established through

its NO

x BACT determination.

Beginning 12/31/2011, Unit 1 will

achieve a phase II NO

x emission

rate established by its BACT

determination. http://www2.e

pa.gov/enforc

ement/minnkot

a

- power

cooperative

and

- square

butte

- electric

cooperative

settlement North

Dakota Unit 2 Design,

upgrade, and

continuously

operate FGD 90% 12/31/10 Install and

continuously

operate over

- fire

AIR, or equivalent

technology with

emission rate <

.36 0.36 12/31/07 0.03 Before

2008

SIGECO

FB Culley Indiana Unit 1 Repower to

natural gas

(or retire) 12/31/06

The provision did not

specify an amount of

SO 2 allowances to

be surrendered. It

only provided that

excess allowances

resulting from

compliance with

NSR settlement

provisions must be

retired. http://www2.e

pa.gov/enforc

ement/souther

n

- indiana

- gas

and

- electric

company

sigeco

- fb

culley

- plant

clean

- a ir

- act

caa Indiana Unit 2 Improve and

continuously

operate

existing FGD

(shared by

Units 2 and 3) 95% 06/30/04

Indiana Unit 3 Improve and

continuously

operate

existing FGD

(shared by

Units 2 and 3) 95% 06/30/04 Operate Existing

SCR Continuously 0.1 09/01/03 Install and

continuously

operate a

Baghouse 0.015 06/30/07

PSEG FOSSIL

Bergen New Jersey Unit 2 Repower to

combined

cycle 12/31/02 The provision did not

specify an amount of

SO 2 allowances to http://www2.e

pa.gov/enforc

ement/pseg

-

## 50 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Hudson New Jersey Unit 2 Install Dry

FGD (or

approved alt.

technology)

and continually

operate 0.15 12/31/10 Install SCR (or

approved tech)

and continually

operate 0.1 12/31/10 Install

Baghouse

(or approved

technology) 0.015 12/31/1 0 be surrendered. It

only provided that

excess allowances

resulting from

compliance with

NSR settlement

provisions must be

retired. The settlement requires coal with

monthly average sulfur content no

greater than 2% at units operating

FGD

-- this limit is modeled as a

coal choice exception in EPA Base

Case. fossil

- llc

settlement

Mercer New Jersey Unit 1 Install Dry

FGD (or

approved alt.

technology)

and continually

operate 0.15 12/31/10 Install SCR (or

approved tech)

and continually

operate 0.1 01/01/07 Install

Baghous e

(or approved

technology)

w/activated

carbon

injection for

Hg control 0.015 12/31/10 The settlement requires coal with

monthly average sulfur content no

greater than 2% at units operating

FGD

-- this limit is modeled as a

coal choice exception in EP A Base

Case. Limits are consistent with

recent Title V permits. http://www2.e

pa.gov/enforc

ement/pseg

fossil

- llc

settlement

New Jersey Unit 2 Install Dry

FGD (or

approved alt.

technology)

and continually

operate 0.15 12/31/10 Install SCR (or

approved tech)

and cont inually

operate 0.1 01/31/07 Install

Baghouse

(or approved

technology)

w/activated

carbon

injection for

Hg control 0.015 12/31/10 The settlement requires coal with

monthly average sulfur content no

greater than 2% at units operating

FGD

-- this limit is modeled as a

coal choice exception in EPA Base

Case.

TECO

Big Bend Florida Unit 1 Existing

Scrubber

(shared by

Units 1 & 2) 95% (95% or

.25) 09/1/00

(01/01/13) Install SCR 0.12 06/01/08 0.03

The provision did not

specify an amount of

SO 2 allowances to

be surrendered. It

only provided that

excess allowances

resulting from

compliance with

NSR settlement

provisions must be

retired. http://www2.e

pa.gov/enforc

ement/tampa

electric

company

teco

- clean

- air

act

- caa

settlement Florida Unit 2 Existing

Scrubber

(sh ared by

Units 1 & 2) 95% (95% or

.25) 09/1/00

(01/01/13) Install SCR 0.12 06/01/09 0.03

Florida Unit 3 Existing

Scrubber

(shared by

Units 3 & 4) 93% if Units

3 & 4 are

operating 2000

(01/01/10) Install SCR 0.12 06/01/10 0.03

Florida Unit 4 Existing

Scrubber

(shared by

Units 3 & 4) 93% if Units

3 & 4 are

operating 06/22/05 Install SCR 0.1 07/01/07

Gannon Florida Six units Retire all six

coal units

and repower

at least 550

MW of coal

capacity to

natural gas 12/31/04

WEPCO

WEPCO shall comply with the following system wide average NO

x emission rates and total NO

x tonnage permissible: by 1/1/2005 an emission rate of 0.27 an d 31,500 tons, by 1/1/2007 an emission rate

of 0.19 and 23,400 tons, and by 1/1/2013 an emission rate of 0.17 and 17, 400 tons. For SO 2 emissions, WEPCO will comply with: by 1/1/2005 an emission rate of 0.76 and 86,900 tons, by 1/1/2007 an

emission rate of 0.61 and 74,400 tons, by 1/1/2008 an emission rate of 0.45 and 55,400 tons, and by 1/1/2013 an emission rate of 0.32 and 3 3,300 tons. http://www2.e

pa.gov/enforc

ement/wiscon

sin

- electric

power

company

wepco

- clean

air

- act

- civil

settlement Presque Isle Wisconsin Units

1

– 4 Retire or

install SO 2 and NO

x controls 12/31/12 Install and

continuously

operate FGD

(or approved

equiv. tech) 95% or 0.1 12/31/12 Install SCR (or

approved tech)

and continually

operate 0.1 12/31/12 The provision d id not

specify an amount of

SO 2 allowances to

be surrendered. It

only provided that

excess allowances

resulting from

compliance with

NSR settlement Wisconsin Units 5,

6 Install and operate

low NO

x burners 12/31/03

## 51 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Wisconsin Units 7,

8 Operate existing

low NO

x burners 12/31/05 Install

Baghouse provisions must be

retired.

Wisconsin Unit 9 Operate existing

low NO

x burners 12/31/06 Install

Baghouse

Pleasant

Prairie Wisconsin Unit 1 Install and

continuously

operate FGD

(or approved

control tech) 95% or 0.1 12/31/06 Install and

continuously

operate SCR (or

approved tech) 0.1 12/31/06

Wisconsin Unit 2 Install and

continuously

operate FGD

(or approved

control tech) 95% or 0.1 12/31/07 Install and

continuously

operat e SCR (or

approved tech) 0.1 12/31/03

Oak Creek Wisconsin Units 5,

6 Install and

continuously

operate FGD

(or approved

control tech) 95% or 0.1 12/31/12 Install and

continuously

operate SCR (or

approved tech) 0.1 12/31/12

Wisconsin Unit 7 Install and

continuously

operate FGD

(or approved

control tech) 95% or 0.1 12/31/12 Install and

continuously

operate SCR (or

approved tech) 0.1 12/31/12

Wisconsin Unit 8 Install and

continuously

operate FGD

(or approved

control tech) 95% or 0.1 12/31/12 Install and

continuously

operate SCR (or

approved tech) 0.1 12/31/12

Port

Washington Wisconsin Units

1

– 4 Retire 12/31/04

for Units 1

– 3. Unit 4

by entry of

consent

decree

Valley Wisconsin Boilers

1

– 4 Operate existing

low NO

x burner 30 days

after

entry of

consent

decree

VEPCO

The Total Permissible NO

x Emissions (in tons) from VEPCO system are: 104,000 in 2003, 95,000 in 2004, 90,000 in 2005, 83,000 in 2006, 81,000 in 2007, 63, 000 in 2008

– 2010, 54,000 in 2011, 50,000

in 2012, and 30,250 each year thereafter. Beginning 1/1/2013 they will have a system wide emission rate no greater than 0.15 lbs/mmBTU.

http://www2.e

pa.gov/enforc

ement/virginia

electric

- and

power

company

vepco

- clean

air

- act

- caa

settlement Mount Storm West

Virginia Units

1

– 3 Construct or

improve FGD 95% or 0.15 01/01/05 Install and

continuously

operate SCR 0.11 01/01/08

On or before March

31 of every year

beginning in 2013

and continuing

thereafter, VEPCO

shall surrender

45,000 SO 2

allowances. Chesterfield Virginia Unit 4 Install and

continuously

operate SCR 0.1 01/01/13

Virginia Unit 5 Construct or

improve FGD 95% or 0.13 10/12/12 Install and

continuously

operate SCR 0.1 01/01/12

Virginia Unit 6 Construct or

improve FGD 95% or 0.13 01/01/10 Install and

continuously

operate SCR 0.1 01/01/11

Chesapeake

Energy Virginia Units 3,

4 Install and

continuously

operate SCR 0.1 01/01/13

## 52 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Clover Virginia Units 1,

2 Improve FGD 95% or 0.13 09/01/03

Possum

Point Virginia Units 3,

4 Retire and

repower to

natural gas 05/02/03

Santee Cooper

Santee Cooper shall comply with the following system wide averages for NO

x emission rates and combined tons for emission of: by 1/01/2005 facility shall c omply with an emission rate of 0.3 and 30,000

tons, by 1/1/2007 an emission rate of 0.18 and 25,000 tons, by 1/1/2010 and emission rate of 0.15 and 20,000 tons. For SO 2 emission the company shall comply with system wide averages of: by

1/1/2005 an emissi on rate of 0.92 and 95,000 tons, by 1/1/2007 and emission rate of 0.75 and 85,000 tons, by 1/1/2009 an emission rate of 0.53 and 70 tons, and by 1/1/2011 and emission rate of 0.5 and

65 tons.

http://www2.e

pa.gov/enforc

ement/south

carolina

public

- service

authority

santee

cooper

settlement Cross South

Carolina Unit 1 Upgrade and

continuously

operate FGD 95% 06/30/06 Install and

continuously

operate SCR 0.1 05/31/04

The provision did not

specify an amount of

SO 2 allowances to

be surrendered. It

only provided that

excess allowances

resulting from

compliance with

NSR settlement

provisions must be

retired. South

Carolina Unit 2 Upgrade and

continuously

operate FGD 87% 06/30/06 Install and

continuously

operate SCR 0.11/0.1 05/31/04

and

05/31/07

Winyah South

Carolina Unit 1 Install and

continuously

operate FGD 95% 12/31/08 Install and

continuously

operate SCR 0.11/0.1 11/30/04

and

11/30/04

South

Carolina Unit 2 Install and

continuously

operate FGD 95% 12/31/08 Install and

continuously

operate SCR 0.12 11/30/04

South

Carolina Unit 3 Upgrade and

continuously

operate

existing FGD 90% 12/31/08 Install and

continuously

operate SCR 0.14/0.12 11/30/20

05 and

11/30/08

South

Carolina Unit 4 Upgrade and

continuously

operate

existing FGD 90% 12/31/07 Install and

continuously

operate SCR 0.13/0.12 11/30/ 05

and

11/30/08

Grainger South

Carolina Unit 1 Operate low NO

x burner or more

stringent

technology 06/25/04

South

Carolina Unit 2 Operate low NO

x burner or more

stringent

technology 05/01/04

Jeffries South

Carolina Units 3,

4 Retire 2012 Operate low NO

x burner or more

stringent

technology 06/25/04

OHIO EDISON

Ohio Edison shall achieve reductions of 2,483 tons NO

x between 7/1/2005 and 12/31/2010 using any combination of: 1) low sulfur coal at Burger Units 4 and 5, 2) operating SCRs currently installed at

Mansfield Units 1

– 3 during the months of October through April, and/or 3) emitting fewer tons than the Plant

- Wide Annual Cap for NO

x required for the Sammis Plant. Ohio Edison must reduce 24,600

tons sy stem

- wide of SO 2 by 12/31/2010. http://www2.e

pa.gov/enforc

ement/ohio

edison

company

- wh

sammis

power

- station

clean

- air

- act

2005

-

settlement

and

- 2009 No later than 8/11/2005, Ohio Edison shall install and operate low NO

x burners on Sammis Units 1, 2,4,5,6, and 7 and overfired air on Sammis Units 1,2,3,6, and 7. No later than 12/1/2005, Ohio Ed ison

shall install advanced combustion control optimization with software to minimize NO

x emissions from Sammis Units 1

– 5.

W.H.

Sammis

Plant Ohio Unit 1 Install Induct

Scrubber (or

approved

equiv.

control tech) 50% removal

or 1.1

lbs/mmBTU 12/31/08 Install SNCR

(or approved

alt. tech) &

operate

continuously 0.25 10/31/07 Beginning on

1/1/2006, Ohio

Edison may use, sell

or transfer any

restricted SO 2 only to

satisfy the

Operational Needs

at the Sammis,

Burger and

Mansfield Plant, or

new units within the Plant

- wide NOx Annua l Caps:

11,371 tons 7/1/2005

– 12/31/2005; 21,251 tons 2006;

20,596 tons 2007; 18,903 tons

2008; 17,328 tons 2009

– 2010;

14,845 tons 2011; 11,863 2012

onward. Sammis Plant

- Wide

Annual SO 2 Caps: 58,000 tons

SO 2 7/1/2005

- 12/31/2005; 116,000

tons 1/1/2006

– 12/31/2007;

114,000 tons 1/1/2008

- 12/31/2008; Ohio Unit 2 Install Induc t

Scrubber (or

approved

equiv.

control tech) 50% removal

or 1.1

lbs/mmBTU 12/31/08 Operate

existing SNCR

continuously 0.25 02/15/06

## 53 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Ohio Unit 3 Install Induct

Scrubber (or

approved

equiv.

control tech) 50% removal

or 1.1

lbs/mmBTU 12/31/08 Operate low NO

x burners and

overfire air by

12/1/05; install

SNCR

(or approved

alt. tech) &

operate

continuously by

12/31/07 0.25 12/01/05

and

10/31/07 FirstEnergy System

that comply with a

96% removal for

SO 2 . For calendar

year 2006 through

2017, Ohio Edison

may accumulate SO 2 allowances for use at

the Sammis, Burger,

and Mansfield

plants, or

FirstEnergy units

equipped with SO 2 Emission Control

Standards.

Beginning in 2018,

Ohio Edison shall

surrender unused

restricted SO 2

allowances. 101,500 tons 1/1/2009

– 12/31/2010; 29,900 tons 1/1/2011

onward. Sammis Units 1

– 5 are

also subject to the following SO 2 Monthly Caps if Ohio Edison

installs the improved SO 2 control

technology (Unit 5's o ption A):

3,242 tons May, July, and August

2010; 3,137 tons June and

September 2010. Ohio Edison has

installed the required SO 2 technology (Unit 5's option B), so

the Monthly Caps are: 2,533 tons

May, July, and August 2010; 2,451

tons June and September 2010.

Add'l Monthly Caps are: 2,533

tons May, July, and August 2011;

2,451 tons June and September

2011 thereafter. Ohio Unit 4 Install Induct

Scrubber (or

approved

equiv.

control tech) 50% removal

or 1.1

lbs/mmBTU 06/30/09 Install SNCR

(or approved

alt. tech) &

op erate

continuously 0.25 10/31/07

Ohio Unit 5 Install Flash

Dryer Absorber

or ECO 2 (or

approved

equiv.

control tech) &

operate

continuously 50% removal

or 1.1

lbs/mmBTU 06/29/09 Install SNCR

(or approved

alt. tech) &

Operate

Continuously 0.29 03/31/08

Ohio Unit 6 Install FGD 3

(or

approved

equiv.

control tech) &

operate

continuously 95% removal

or 0.13

lbs/mmBTU 06/30/11 Install SNCR

(or approved

alt. tech) &

operate

continuously "Minimum

Extent

Practicable

" 06/30/05 Operate

Existing

ESP

Continuously 0.03 01/01/10 In addition to SNCR, settlement

requires installation of first SCR (or

approved alt tech) on either Unit 6

or 7 by 12/31/2010; second

installation by 12/31/2011. Both

SCRs must achieve 90% Design

Removal Efficiency by 180 days

after installation date. Each SCR

must provide a 30

- Day Rolling

average. NO

x Emission Rate of

0.1 lbs/mmBTU starting 180 days

after installation dates above. Ohio Unit 7 Install FGD (or

approved

equiv.

control tech) &

operate

continuously 95% removal

or 0.13

lbs/mmBTU 06/30/11 Operate

existing SNCR

Continuously "Minimum

Extent

Practicable

" 08/11/05 Operate

Existing

ESP

Continuously 0.03 01/01/10

Mansfield

Plant Pennsylvani

a Unit 1 Upgrade

existing FGD 95% 12/31/05 Additional Mansfield Plant

- wide

SO 2 reductions are as follows:

4,000 tons in 2006, 8,000 tons in

2007, and 12,000 tons/yr for every

year after. Settlement allows

relinquishment of SO 2 requirement

upon shutdown of unit, after which

the SO 2 reductions must be made

by another plant(s). Pennsylvani

a Unit 2 Upgrade

existing FGD 95% 12/31/06

Pennsylvani

a Unit 3 Upgrade

existing FGD 95% 10/31/07

Eastlake Ohio Unit 5 Install low NO

x burners, over

- fired

air and SNCR &

operate

continuously "Minimize

Emissions

to the

Extent

Practicable

" 12/31/06 Settlement requires Eastlake Plant

to achieve additional reductions of

11,000 tons of NO

x per year

commencing in calendar year

2007, and no less than 10,000

tons must come from this unit.

The extra 1,000 tons may come

from this unit or another unit in the

region. Upon shutd own of

Eastlake, another plant must

achieve these reductions.

Burger Ohio Unit 4 Repower

with at least

80%

biomass fuel,

up to 20%

low sulfur

coal OR

Retire by

12/31/2010 12/31/11

Ohio Unit 5 12/31/11

## 54 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

MIRANT 1,6

System

- wide NO

x Emission Annual Caps: 36,500 tons 2004; 33,840 tons 2005; 33,090 tons 2006; 28,920 tons 2007; 22,000 tons 2008; 19,650 tons 2009; 16,000 tons 2010 onward. System

- wide NO

x Emission Ozone Season Caps: 14,700 tons 2004; 13,340 tons 2005; 12,590 tons 2006; 10,190 tons 2007; 6,150 tons 2008

– 2009; 5,200 tons 2010 thereafter. Beginning on 5/1/2008, and continuing for

each and every Ozone Season thereafter, the Mirant System shall not exceed a System

- wide Ozone Season Emission Rate of 0.150 lbs/mmBTU NO

x

.

http://www2.e

pa.gov/enforc

ement/mirant

clean

- air

settlement Potomac

River Plant Virginia Unit 1

Retire 12/21/2012 Virginia Unit 2

Virginia Unit 3 Install low NO

x burners (or more

effective tech) &

operate

continuously 05/01/04

Settlement requires installation of

Separated Overfire Air tech (or

more effective technology) by

5/1/2005. Plant

- wide Ozone

Season NO

x Caps: 1,750 tons

2004; 1,625 tons 2005; 1,600 tons

2006

– 2009; 1,475 tons 2010

thereafter. Plant

- wide annual NO

x Caps are 3,700 tons in 2005 and

each year thereafter. Virginia Unit 4 Install low NO

x burners (or more

effective tech) &

operate

continuously 05/01/04

Virginia Unit 5 Install low NO

x burners (or more

effective tech) &

operate

continuously 05/01/04

Morgantown

Plant Maryland Unit 1 Install SCR

(or approved

alt. tech) &

operate

continuously 0.1 05/01/07

Maryland Unit 2 Install SCR

(or approved

alt. tech) &

operate

continuously 0.1 05/01/08

Chalk Point Maryland Unit 1 Install and

continuously

operate FGD

(or equiv.

technology) 95% 06/01/10 For each year after

Mirant commences

FGD operation at

Chalk Point, Mirant

shall surrender the

number of SO 2 Allowances equal to

the amount by which

the SO 2 Allowances

allocated to the Units

at the Chalk Point

Plant are greater

than the total amount

of SO 2 emissions

allowed under this

Section XVIII. Mirant must install and op erate

FGD by 6/1/2010 if authorized by

court to reject ownership interest in

Morgantown Plant, or by no later

than 36 months after they lose

ownership interest of the

Morgantown Plant. [Installed] Maryland Unit 2 Install and

continuously

operate FGD

(or equiv.

technology) 95% 06/01/10

ILLINOIS POWER

System

- wide NO

x Emission Annual Caps: 15,000 tons 2005; 14,000 tons 2006; 13,800 tons 2007 onward. System

- wide SO 2 Emission Annual Caps: 66,300 tons 2005

– 2006; 65,000 tons 2007; 62,000

tons 2008

– 2010; 57,000 tons 2011; 49,500 tons 2012; 29,000 tons 2013 onward. http://www2.e

pa.gov/enforc

ement/illinois

power

company

- and

dynegy

midwest

generation

settlement Baldwin Illinois Unit 1 Install wet or

dry FGD (or

approved

equiv.

alt. tech) &

operate

continuously 0.1 12/31/11 Operate OFA &

existing SCR

continuously 0.1 08/11/05 Install &

continuously

operate

Baghouse 0.015 12/31/10 By year end 2008,

Dynegy will

surrender 12,000

SO 2 emission

allowances, by year

end 2009 it will

surrender 18,000, by

## 55 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Illinoi s Unit 2 Install wet or

dry FGD (or

approved

equiv.

alt. tech) &

operate

continuously 0.1 12/31/11 Operate OFA &

existing SCR

continuously 0.1 08/11/05 Install &

continuously

operate

Baghouse 0.015 12/31/10 year end 2010 it will

surrender 24,000,

any by year end

2011 and each year

thereafter it will

surrender 30,000

allowances. If the

surrendered

allowances re sult in

insufficient remaining

allowances allocated

to the units

comprising the DMG

system, DMG can

request to surrender

fewer SO 2

allowances. Illinois Unit 3 Install wet or

dry FGD (or

approved

equiv.

alt. tech) &

operate

continuously 0.1 12/31/11 Operate OFA

and/or low NO

x

burners 0.12 until

12/30/12;

0.1

from

12/31/12 08/11/05

and

12/31/12 Install &

continuously

operate

Baghouse 0.015 12/31/10

Havana Illinois Unit 6 Install wet or

dry FGD (or

approved

equiv.

alt. tech) &

operate

continuously 1.2

lbs/mmBTU

until

12/30/2012;

0.1

lbs/mmBTU

from

12/31/2012

onward 08/11/05

and

12/31/12 Operate OFA

and/or low NO

x burners & operate

existing SCR

continuously 0.1 08/11/05 Install &

continuously

operate

Baghouse,

then install

ESP or alt.

PM equip For Bag

house:

.015

lbs/mmBT

U; For

ESP: .03

lbs/m mBT

U For

Baghous

e:

12/31/12

;

For ESP:

12/31/05

Hennepin Illinois Unit 1 1.2 07/27/05 Operate OFA

and/or low NO

x

burners "Minimum

Extent

Practicable

" 08/11/05 Install ESP

(or equiv. alt.

tech) &

continuously

operate

ESPs 0.03 12/31/06 Settlement requires first installation

of ESP at either Unit 1 or 2 on

12/31/2006; and on the other by

12/31/2010.

Illinois Unit 2 1.2 07/27/05 Operate OFA

and/or low NO

x

burners "Minimum

Extent

Practicable

" 08/11/05 Install ESP

(or equiv. alt.

tech) &

continuously

operate

ESPs 0.03 12/31/06

Vermilion Illinois Unit 1 1.2 01/31/07 Operate OFA

and/or low NO

x

burners "Minimum

Extent

Practicable

" 08/11/05 Install ESP

(or equiv. alt.

tech) &

continuously

operate

ESPs 0.03 12/31/10

## 56 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Illinois Unit 2 1.2 01/31/07 Operate OFA

and/or low NO

x

burners "Minimum

Extent

Practicabl e

" 08/11/05 Install ESP

(or equiv. alt.

tech) &

continuously

operate

ESPs 0.03 12/31/10

Wood River Illinois Unit 4 1.2 07/27/05 Operate OFA

and/or low NO

x

burners "Minimum

Extent

Practicable

" 08/11/05 Install ESP

(or equiv. alt.

tech) &

continuously

operate

ESPs 0.03 12/31/05 Settlement requires first installation

of ESP at either Unit 4 or 5 on

12/31/2005; and on the other by

12/31/2007.

Illinois Unit 5 1.2 07/27/05 Operate OFA

and/or low NO

x

burners "Minimum

Extent

Practicable

" 08/11/05 Install ESP

(or equiv. alt.

tech) &

continuo usly

operate

ESPs 0.03 12/31/05

Kentucky Utilities Company

EW Brown

Generating

Station Kentucky Unit 3 Install FGD 97% or

0.100 12/31/10 Install and

continuously

operate SCR by

12/31/2012,

continuously

operate low NO

x boiler and OFA. 0.07 12/31/12 Continuously

operate ESP 0.03 12/31/10 KU must surrender

53,000 SO 2 allowances of 2008

or earlier vintage by

March 1, 2009. All

surplus NO

x allowances must be

surrendered through

2020. SO 2 and NO

x allowances may not be

used for compliance,

and emissions

decreases for

purposes of complying

with the Consent

Decree do not earn

credits. Annual SO 2 cap is 31,998 tons

through 2010, then 2,300 tons

each year thereafter. Annual NO

x cap is 4,072 tons. http://www2.e

pa.gov/enforc

ement/kentuck

y

- utilities

company

clean

- air

- act

settlement

Salt River Projec t Agricultural Improvement and Power District (SRP)

Coronado

Generating

Station Arizona Unit 1 or

Unit 2 Immediately

begin

continuous

operation of

existing FGDs

on both units,

install new

FGD. 95% or 0.08 New FGD

installed by

1/1/2012 Install and

continuously

operate low NO

x burner and SCR 0.32 prior

to SCR

installation,

0.080 after LNB by

06/01/20

09, SCR

by

06/01/20

14 Optimization

and

continuous

operation of

existing

ESPs. 0.03 Optimiza

tion

begins

immediat

ely, rate

limit

begins

01/01/12

(date of

n ew

FGD

installatio

n) Beginning in 2012,

all surplus SO 2 allowances for both

Coronado and

Springerville Unit 4

must be surrendered

through 2020. The

allowances limited

by this condition

may, however, be

used for compliance

at a prospective

future plant usi ng SO 2 and NO

x allowances may not be

used for compliance,

and emissions

decreases for

purposes of complying

with the Consent

Decree do not earn

credits. Annual plant

- wide NO

x cap is

7,300 ton s after 6/1/2014. http://www2.e

pa.gov/enforc

ement/salt

river

- project

agriculture

improvement

and

- power

district

settlement

## 57 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Arizona Unit 1 or

Unit 2 Install new

FGD 95% or 0.08 01/01/13 Install and

continuously

operate low N O

x burner 0.32 06/01/11 Optimiza

tion

begins

immediat

ely, rate

limit

begins

01/01/13

(date of

new

FGD

installatio

n) BACT and otherwise

specified in par. 54

of the consent

decree.

American Electric Power

Eastern System

- Wide [Modified

Limits for SO 2 ] Annual Cap

(tons) Year

http://www.ct.g

ov/ag/lib/ag/pr

ess_releases/

2013/2013022

5_aep_cdmod

.pdf 145,000 2016

- 2018

113,000 2019

- 2021

110,000 2022

- 2025

102,000 2026

- 2028

94,000 2029 and

thereafter

Eastern System

- Wide Annual Cap

(tons) Year Annual

Cap (tons) Year

NO

x and SO 2

allowances that

would have been

made available by

emission reductions

pursuant to the

Consent Decree

must be

surrendered. NO

x and SO 2 allowances may not be

used to comply with

any of the limits

imposed by the

Consent Decree. The

Consent Decree

includes a formula for

calculating excess NO

x allowances relative to

the CSAPR

Allocations, and

restricts the use of

some. See par. 74

- 79

for det ails. Reducing

emissions below the

Eastern System

- Wide

Annual Tonnage

Limitations for NO

x and

SO 2 earns

supercompliant

allowances. http://www2.e

pa.gov/enforc

ement/americ

an

- electric

power

- service

corporation 450,000 2010 96,000 2009

450,000 2011 92,500 2010

420,000 2012 92,500 2011

350,000 2013 85,000 2012

340,000 2014 85,000 2013

275,000 2015 85,000 2014

260,000 2016 75,000 2015

235,000 2017 72,000 2016 and

thereafter

184,000 2018

174,000 2019 and

thereafter

At least

600MW from

various units West

Virginia Sporn

1

– 4

Retire,

retrofit, or re

power 12/31/18 Sporn 1

- 4 will be retired

Virginia Clinch

River

1

– 3

Indiana Tanners

Creek

1

– 3

West

Virginia Kammer

1

– 3 Kammer 1

- 3 will be retired

## 58 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Amos West

Virginia Unit 1 Install and

continuously

operate FGD 12/31/09 Install and

continuously

operate SCR 01/01/08

West

Virginia Unit 2 Install and

continuously

operate FGD 12/31/10 Install and

continuously

operate SCR 01/01/09

West

Virginia Unit 3 Install and

continuously

operate FGD 12/31/09 Install and

continuously

operate SCR 01/01/08

Big Sandy Kentucky Unit 1 Burn only coal

with no more

than 1.75

lbs/mmBTU

annual

average Date of

entry Continuously

operate low NO

x

burners Date of

entry

Kentucky Unit 2 Install and

continuously

operate FGD 12/31/15 Install and

continuously

operate SCR 01/01/09

Cardinal Ohio Unit 1 Install and

continuously

operate FGD 12/31/08 Install and

continuously

operate SCR 01/01/09 Continuously

operate ESP 0.03 12/31/09

Ohio Unit 2 Install and

continuously

operate FGD 12/31/08 Install and

continuously

operate SCR 01/01/09 Continuously

operate ESP 0.03 12/31/09

Ohio Unit 3 Install and

continuously

operate FGD 12/31/12 Install and

continuously

operate SCR 01/01/09

Clinch River Virginia Units

1

– 3 Plant

- wide

annual cap:

21,700 tons

from 2010 to

2014, then

16,300 after

1/1/2015 2010

– 2014, 2015

and

thereafter Continuously

operate low NO

x

burners Date of

entry

Conesville Ohio Unit 1 Retire,

retrofit, or re

power Date of

entry

Ohio Unit 2 Retire,

retrofit, or re

power Date of

entry

Ohio Unit 3 Retire,

retrofit, or re

power 12/31/12

Ohio Unit 4 Install and

continuously

operate FGD 12/31/10 Install and

continuously

operate SCR 12/31/10

Ohio Unit 5 Upgrade

existing FGD 95% 12/31/09 Continuously

operate low NO

x

burners Date of

entry

Ohio Unit 6 Upgrade

existing FGD 95% 12/31/09 Continuously

operate low NO

x

burners Date of

entry

Gavin Ohio Unit 1 Install and

continuously

operate FGD Date of

entry Install and

continuously

operate SCR 01/01/09

## 59 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Ohio Unit 2 Install and

continuously

operate FGD Date of

entry Install and

continuously

operate SCR 01/01/09

Glen Lynn Virginia Units

1

– 3

Virginia Units 5,

6 Burn only coal

with no more

than 1.75

lbs/mmBTU

annual

average Date of

entry Continuously

operate low NO

x

burners Date of

entry

Kammer West

Virginia Units

1

– 3 Plant

- wide

annual cap:

35,000 01/01/10 Continuously

operate over

- fire

air Date of

entry

Kanawha

River West

Virginia Units 1,

2 Burn only coal

with no more

than 1.75

lbs/mmBTU

annual

average Date of

entry Continuously

operate low NO

x

burners Date of

entry

Mitchell West

Virginia Unit 1 Install and

continuously

operate FGD 12/31/07 Install and

continuously

operate SCR 01/01/09

West

Virginia Unit 2 Install and

continuously

operate FGD 12/31/07 Install and

continuously

operate SCR 01/01/09

Mountaineer West

Virginia Unit 1 Install and

continuously

operate FGD 12/31/07 Install and

continuously

operate SCR 01/01/08

Muskingum

River Ohio Units

1

– 4 Retire,

retrofit, or re

power 12/31/15

Ohio Unit 5 Install and

continuously

operate FGD 12/31/15 Install and

continuously

operate SCR 01/01/08 Continuously

operate ESP 0.03 12/31/02

Picway Ohio Unit 9 Continuously

operate low NO

x

burners Date of

entry

Rockport Rockport Units 1 & 2 shall not exceed an Annual Tonnage Limit of 28 MTons of SO 2 in 2016

- 2017, 26 Mtons in 2018

- 2019, 22 MTons in 2020

- 2025, 18 MTons in 2026

- 2028 and 10 MTons in 2029 and

each year t hereafter.

Indiana Unit 1 Install DSI

__ Install and

continuously

operate FGD 4/16/2015

__ 12/31/2025 Install and

continuously

operate SCR 12/31/25

Indiana Unit 2 Install DSI

__ Install and

continuously

operate FGD 4/16/2015

__ 12/31/2028 Install and

continuously

operate SCR 12/31/28

Sporn West

Virginia Unit 5 Retire,

retrofit, or re

power 12/31/13

Tanners

Creek Indiana Units

1

– 3 Burn only coal

with no more

than 1.2

lbs/mmBTU

annual

average Date of

entry Continuously

operate low NO

x

burners Date of

entry

## 60 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Indiana Unit 4 Burn only coal

with no more

than 1.2%

sulfur content

annual

average Date of

entry Continuously

operate over

- fire

air Date of

entry

East Kentucky Power Cooperative Inc.

Dale Plant Kentucky Unit 1 Install and

continuously

operate low NO

x

burners by

10/31/2007 0.46 01/01/08 EKPC must

surrender 1,000 NO

x allowances

immediately under

the ARP, and 3,107

under the NO

x SIP

Call. EKPC must

also surrender

15,311 SO 2

allowances. Date of

entry

http://www2.e

pa.gov/enforc

ement/east

kentucky

power

cooperative

settlement Kentucky Unit 2 Install and

continuously

operate low NO

x

burners by

10/31/2007 0.46 01/01/08

System

- wide Kentucky By 12/31/2009, EKPC shall choose whether to: 1) install and continuously operate NO

x controls at Cooper 2 by 12/31/2012 and SO 2 controls by 6/30/2012 or 2) retire Dale 3 and Dale 4 by 12/31/2012.

12

- month

rolling limit

(tons) Start of 12

- month

cycle 12

- month

rolling limit

(tons) Start of

12

- month

cycle

System

- wide

12

- month

rolling tonnage

limits apply 57,000 10/01/08

All units must

operate low NO

x boilers 11,500 01/01/08 PM control

devices must

be operated

continuously

system

- wide,

ESPs must

be optimized

within 270

days of entry

date, or

EKPC may

choose to

submit a PM

Pollution

Control

Upgrade

Analysis. 0.03 1 year

from

entry

date All surplus SO 2 allowances must be

surrendered each

year, beginning in

2008. SO 2 and NO

x allowances may not be

used t o comply with

the Consent Decree.

NO

x allowances that

would become

available as a result of

compliance with the

Consent Decree may

not be sold or traded.

SO 2 and NO

x allowances allocated

to EKPC must be used

within the EKPC

system. Allowances

made avail able due to

supercompliance may

be sold or traded. 40,0 00 07/01/11 8,500 01/01/13

28,000 01/01/13 8,000 01/01/15

Spurlock Kentucky Unit 1 Install and

continuously

operate FGD 95 % or 0.1 6/30/2011 Continuously

operate SCR 0.12 for

Unit 1 until

01/01/2013

, at which

point the

unit limit

drops to

0.1. Prior

to

01/01/2013

, the

combined

average

when both

units are

operating

must be no

more than

0.1 60 days

after

entry

## 61 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Kentucky Unit 2 Install and

continuously

operate FGD

by 10/1/2008 95% or 0.1 1/1/2009 Continuously

operate SCR and

OFA 0.1 for Unit

2, 0.1

combined

average

when both

units are

operating 60 days

after

entry

Dale Plant Kentucky Unit 3 EKPC may

choose to

retire Dale 3

and 4 in lieu

of installing

controls in

Cooper 2 12/31/2012

Kentucky Unit 4

Cooper Kentucky Unit 1

Kentucky Unit 2 If EKPC opts

to install

controls rather

than retiring

Dale, it must

install and

continuously

operate FGD

or equiv.

technology 95% or 0.10 If EKPC elects to

install controls, it

mus t continuously

operate SCR or

install equiv.

technology 0.08 (or

90% if non

SCR

technology

is used) 12/31/12 EKPC has installed a DFGD on

this unit and Dale continues to

operate.

Nevada Power Company

Beginning 1/1/2010, combined NO

x emissions from Units 5, 6, 7, and 8 must be no more than 360 tons per year.

Clark

Generating

Station Nevada Unit 5

Units may

only fire

natural gas Increase water

injection

immediately, then

install and operate

ultra

- low NO

x burners (ULNBs)

or equivalent

technology. In

2009, Units 5 and

8 may not emit

more than 180

tons combined 5ppm 1

- hour

average 12/31/08

(ULNB

installatio

n),

01/30/09

(1

- hour

average)

Allowances may not be

used to comply with

the Consent Decree,

and no allowances

made available due to

compliance with the

Consent Decree may

be traded or sold. http://www2.e

pa.gov/enforc

ement/nevada

- power

company

clea n

- air

- act

caa

- settlement Nevada Unit 6 5ppm 1

-

hour

average 1 2/31/09

(ULNB

installatio

n),

01/30/10

(1

- hour

average)

Nevada Unit 7 5ppm 1

- hour

average 12/31/09

(ULNB

installatio

n),

0 1/30/10

(1

- hour

average)

Nevada Unit 8 5ppm 1

- hour

average 12/31/08

(ULNB

installatio

n),

0 1/30/09

(1

- hour

average)

Dayton Power & Light

Non

- EPA Settlement of 10/23/2008

Stuart

Generating

Station Ohio Station

wide Complete

installation of

FGDs on each

unit. 96% or 0.10 07/31/09 Owners may not

purchase any new

catalyst with SO 2 to SO 3 conversion

rate greater than

0.5% 0.17

station

wide 30 days

after

entry 0.030 lbs

per unit 07/31/09 NO

x and SO 2 allowances may not be

used to comply with

the monthly rates

specified in the

Consent Decree.

## 62 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

0.17

station

wide 60 days

after

entry

date

82%

including

data from

periods of

malfunctions 7/31/09

through

7/30/11 Install control

technology on one

unit 0.10 on

any single

unit 12/31/12

Install

rigid

- type

electro

- des

in each

unit's ESP 12/31/15

82%

including

data from

periods of

malfunctions after

7/31/11 0.15

station

wide 07/01/12

0.10

station

wide 12/31/14

PSEG FOSSIL, Amended Consent Decree of November 2006

Kearny New Jersey Unit 7 Retire unit 01/01/07

Allowances allocated

to Kearny, Hudson,

and Mercer may only

be used for the

operational needs of

those units, and all

surplus allowances

must be

surrendered. Within

90 days of amended

Consent Decree,

PSEG must

surrender 1,230 NO

x

Allowances and

8,56 8 SO 2

Allowances not

already allocated to

or generated by the

units listed here.

Kearny allowances

must be surrendered

with the shutdown of

those units. http://www2.e

pa.gov/enforc

ement/pseg

fossil

- llc

settlement New Jersey Unit 8 Retire unit 01/01/07

Hudson New Jersey Unit 2 Install Dry

FGD (or

approved alt.

technology)

and continually

operate 0.15 12/31/10 Install SCR (or

approved tech)

and continually

operate 0.1 12/31/10 Install

Baghouse

(or approved

technology) 0.015 12/31/10

Annual Cap

(tons) Year Annual

Cap (tons) Year

5,547 2007 3,486 2007

5,270 2008 3,486 2008

5,270 2009 3,486 2009

5,270 2010 3,486 2010

Merce r New Jersey Unit 1 Install Dry

FGD (or

approved alt.

technology)

and continually

operate 0.15 12/31/10 Install SCR (or

approved tech)

and continually

operate 0.1 01/01/07 Install

Baghouse

(or approved

technology) 0.015 12/31/10

New Jersey Unit 2 Install Dry

FGD (or

approved alt.

technology)

and continually

operate 0.15 12/31/10 Install SCR (or

approved tech)

and continually

operate 0.1 01/01/07 Install

Baghouse

(or approved

technology) 0.015 12/31/10

Westar Energy

## 63 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Jeffrey

Energy

Center Kansas All units Units 1, 2, and 3 have a total annual limit

of 6,600 tons of SO 2 starting 2011

Units 1, 2, and 3 must all install FGDs by

2011 and operate them continuously.

FGDs must maintain a 30

- Day Rolling

Average Unit Removal Efficiency for SO 2

of at least 97% or a 30

- Day Rolling

Average Unit Emission Rate for SO 2 of

no greater than 0.070 lbs/mmBTU. Units 1

- 3 must continuously operate Low

NO

x Combustion Systems by 2012 and

achieve and maintain a 30

- Day Rolling

Average Unit Emission Rate for NO

x of

no greater than 0.180 lbs/mmBTU.

One of the three units must insta ll an

SCR by 2015 and operate it continuously

to maintain a 30

- Day Rolling Average

Unit Emission Rate for NO

x of no greater

than 0.080 lbs/mmBTU.

By 2013 Westar shall elect to either (a)

install a second SCR on one of the other

JEC Units by 2017 or (b) me et a 0.100

lbs/mmBTU Plant

- Wide 12

- Month Rolling

Average Emission Rate for NO

x by 2015 Units 1, 2, and 3 must operate

each ESP and FGD system

continuously by 2011 and maintain

a 0.030 lbs/mmBTU PM Emissions

Rate.

Units 1 and 2’s ESPs must be

rebuilt by 2 014 in order to meet a

0.030 lbs/mmBTU PM Emissions

Rate http://www2.e

pa.gov/enforc

ement/westar

energy

- inc

settlement

Duke Energy

Gallagher Indiana Units 1 &

3 Retire or

repower as

natural gas 1/1/2012 http://www2.e

pa.gov/enforc

ement/duke

energy

gallagher

plant

- clean

air

- act

settlement Units 2 &

4 Install Dry

sorbent

injection

technology 80% 1/1/2012

American Municipal Power

Gorsuch

Station Ohio Units 2 &

3

Elected to Retire Dec 15,

2010 (must retire by Dec

31, 2012) http://www2.e

pa.gov/enforc

ement/americ

an

- municipal

power

- clean

air

- act

settlement Units 1 &

4

Hoosier Energy Rural Electric Cooperative

Ratts Indiana Units 1 &

2 Install &

continually

operate SNCRS 0.25 12/31/20

11 Continuously operate ESP

Annually surrender any NO

x and SO 2 allowances that

Hoosier does not need in order to meet its regulatory

obligations http://www2.epa.go

v/enforcement/hoos

ier

- energy

- rural

electric

cooperative

- inc

settlement

Merom Indiana Unit 1 Continuously

run current

FGD for 90%

removal and

update FGD

for 98%

removal by

2012 98% 2012

Continuously

operate existing

SCRs 0.12 Continuously operate ESP and

achieve PM rate no greater than

0.007 by 6/1/12

Unit 2 Continuously

run current

FGD for 90%

removal and

update FGD

for 98%

removal by

2014 98% 2014 Continuously operate ESP and

achieve PM rate no greater than

0.007 by 6/1/13

Northern Indiana Public Service Co.

Bailly Indiana Units 7 &

8 Upgrade

existing FGD 95% by 01/01/11

97% by 01/01/14 (95% if

low sulfur coal only is

burned) OFA & SCR 0.15 lbs/mmBTU by

12/31/10

0.13 lbs/mmBTU by

12/31/13

0.12 lbs/mmBTU by

12/31/15 0.3

lbs/mmBT

U (0.015 if

a

Baghouse

is installed) 12/31/20

10 http://www2.e

pa.gov/enforc

ement/norther

n

- indiana

public

- service

company

-

## 64 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Michigan

City Indiana Unit 12 FGD 0.1

lbs/mmBTU 12/31/2018 OFA & SCR 0.14 lbs/mmBTU by

12/31/10

0.12 lbs/mmBTU by

12/3 1/11

0.10 lbs/mmBTU by

12/31/13 0.3

lbs/mmBT

U (0.015 if

a

Baghouse

is installed) 12/31/20

18 clean

- air

- act

settlement

Schahfer Indiana Unit 14 FGD 0.08

l bs/mmBTU 12/31/2013 OFA & SCR 0.14 lbs/mmBTU by

12/31/10

0.12 lbs/mmBTU by

12/31/12

0.10 lbs/mmBTU by

12/31/14 0.3

lbs/mmBT

U (0.015 if

a

baghouse

is installed) 12/31/20

13

Indiana Unit 15 FGD 0.08

lbs/mmBTU 12/31/2015 LNB/OFA 0.16 3/31/201

1 0.3

lbs/mmBT

U (0.015 if

a

baghouse

is installed) 12/3 1/20

15 Either: SCR or

SNCR 0.08 12/31/20

15

0.15 12/31/20

12

Indiana Units 17

& 18 Upgrade

existing FGD 97% 1/31/2011 LNB/OFA 0.2 3/31/201

1 0.3

lbs/mmBT

U (0.015 if

a

baghouse

is installed) 12/31/20

10

Dean H

Mitchell Indiana Units 4,

5, 6, &

11 Retire 12/31/2010

Tennessee Valley Authority

Colbert Alabama Units 1

-

4 FGD 6/30/2016 SCR 6/30/201

6

Shall surrender all

calendar year NO

x and SO 2 Allowances

allocated to TVA that

are not needed for

compliance with its

own CAA reqts.

Allocated allowances

may be used for

TVA’s own

compliance with

CAA reqts. Shall not use NO

x or

SO 2 Allowances to

comply with any

requirement of the

Consent Decree,

Nothing prevents TVA

from purchasing or

otherwise obtaining

NO

x and SO 2 allowances from other

sources for its

compliance with CAA

reqts.

TVA may sell, bank,

use, trade, or t ransfer

any NO

x and SO 2 Super

- Compliance”

Allowances resulting

from meeting System

wide limits. Except

that reductions used to

support new CC/CT

will not be Super

Allowances in that year

and thereafter. 2011 http://www2.e

pa.gov/enforc

ement/tenness

ee

- valley

authority

clean

- air

- act

settlementl Unit 5 FGD 12/31/15 SCR Effective

Date

Widows

Creek Alabama Units 1

-

6 Retire 2 units 7/31/13

Retire 2 units 7/31/14

Retire 2 units 7/31/15

Unit 7 Continuously operate FGD SCR Effective

Date

Unit 8 Continuously operate FGD SCR Effective

Date

Paradise Kentucky Units 1 &

2 Upgrade FGD 93% 12/31/12 SCR Effective

Date

Unit 3 Wet FGD Effective

Date SCR Effective

Date

Shawnee Kentucky Units 1 &

4 FGD 1.2 12/31/17 SCR 12/31/17

Units 5

-

10 1.2 Effective

Date

Allen Tennessee Units 1

-

3 FGD 12/31/18 Continuously

operate SCR 0.3 12/31/18

Bull Run Tennessee Unit 1 Wet FGD Effective

Date Continuously

operate SCR 0.3 Effective

Date

Cumberland Tennessee Units 1 &

2 Wet FGD Effective

Date Continuously

operate SCR

Gallatin Tennessee Units 1

-

4 FGD 12/31/17 SCR 12/31/17 0.3 12/31/17

John Sevier Tennessee Units 1 &

2 Retire 2 Units 12/31/12

and 12/31/15

Units 3 &

4 FGD 12/31/15 SCR 12/31/15

Johnsonville Tennessee Units 1

-

10 Retire 6 Units 12/31/15

Retire 4 Units 12/31/17

## 65 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

K ingston Tennessee Units 1

-

9 FGD Effective

Date SCR Effective

Date 0.3 Effective

Date

Wisconsin Public Service

Pulliam Wisconsin Units 5

- 6 Retire, refuel

or repower

as natural

gas 6/1/2015 0.750

lbs/mmBTU 1/1/2013

until

retirement

http://www2.e

pa.gov/enforc

ement/wiscon

sin

- public

service

corporation

settlement Wisconsin Units 7

- 8 0.750

lbs/mmBTU

& plant

- wide

cap of 2100

tons starting

2016 1/1/ 2013 0.250

lbs/mmBT

U & plant

wide cap of

1500 tons

starting

2016 12/31/12 The modeled SO 2 rate in IPM is

lower; only tonnage limitation

imposed through a constraint.

Weston Wisconsin Unit 1 0.750

lbs/mmBTU 1/1/2013

until

retirement 0.250

lbs/mmBT

U 12/31/20

12 until

retiremen

t

Wisconsin Units 2 Retire, refuel

or repower

as natural

gas 6/1/2015 0.750

lbs/mmBTU 1/1/2013

until

retirement 0.280

lbs/m mBT

U 12/31/20

12 until

retiremen

t

Wisconsin Units 3 ReACT by

12/31/2016 0.750

lbs/mmBTU

until 2016

0.080

lbs/mmBTU

2016

onwards 12/31/16 ReACT by

12/31/2016 0.130

lbs/mmBT

U until

2016

0.100

lbs/mmBT

U 2016

onwards 12/31/16

Wisconsin Units 4 Continu ously

Operate the

existing DFGD

& burn only

Powder River

Basin Coal 0.080

lbs/mmBTU 2/31/2013 Continuously

Operate the

existing SCR 0.060

lbs/mmBT

U 2/31/201

3

Louisiana Generating LLC

Plant

- Wide Annual Tonnage Limitations for SO 2 is 18,950 tons in

2016 and thereafter Plant

- Wide Annual Tonnage Limitations

for NO

x is 8,950 tons in 2015 and

thereafter

Big Cajun 2 Louisiana Unit 1 Retirement,

Refueling,

Repowering,

or Retrofit 04/01/25 install and

Continuously

Operate DSI

__

install and

Continuously

Operate Dry

FGD 0.380

lbs/mmBTU

[2015]

__

0.070

lbs/mmBTU 4/15/2015

[DSI]

__

4/1/2025

[DFGD] install and

Continuously

Operate SNCR 0.150

lbs/mmBT

U 05/01/14 Continuously

Operate

each ESP 0.030

lbs/mmBT

U 04/15/15 May trade Super

- Compliant

Allowances, may buy external

allo wances to comply.

“Commencing January 1, 2013,

and continuing thereafter, Settling

Defendant shall burn only coal with

no greater sulfur content than 0.45

percent by weight on a dry basis at

Big Cajun II Units 1 and 3. “ http://www2.e

pa.gov/enforc

ement/lo uisian

a

- generating

settlement

Unit 2 Refuel/conve

rt to NG fired 04/15/15 install and

Continuously

Operate SNCR 0.150

lbs/mmBT

U 05/01/14

Unit 3 install and

Continuously

Operate SNCR 0.135

lbs/mmBT

U 05/01/14 Continuously

Operate

each ESP 0.030

lbs/mmBT

U 04/15/15

## 66 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Dairyland Power Cooperative

Dairyland Power Cooperative shall not exceed an Annual Plant

- wide Tonnage Limitation of 6800 tons of NO

x in calendar years 2016, 3700 tons 2017

- 2019, and 3200 tons in 2020 and thereafter; and an

Annual Plant

- wide Tonnage Limitation of 6070 tons of SO 2 in 2016, 6060 tons 2017

- 2019 and 4580 tons in 2020 and thereafter.

Alma Wisconsin Unit 1 Cease

Burning Coal 06/30/12

http://www2.e

pa.gov/enforc

ement/dairylan

d

- power

cooperative

settlement Unit 2 Cease

Burning Coal 06/30/12

Unit 3 Cease

Burning Coal 06/30/12

Unit 4

Option 2 :

Retrofit and

Regulate

both units

more

stringently 12/31/14 Install and

continuously

operate DFGD

or DSI at Alma

4 1.00

lbs/mmBTU

at A lma 4

And a joint

cap of 3,737

tons until

2019, and

2,242 tons

thereafter. In

the event

that one

retires,

Tonnage

Cap of 2,136

tons for the

remaining

unit until

2019 and

1,282 tons

thereafter 12/31/2014 Continuously

Operate the

existing Low NO

x

Combustion

System

(including OFA)

and SNCR 0.350

lbs/mmBT

U

__

Joint cap

of 1308

tons for

until 2019,

and 785

tons

thereafter.

In the

event that

one retires,

Tonnage

Cap of 746

tons for

remaining

unit until

2019 and

449 tons

thereafter 8/1/2012

__

12/31/20

14 C ontinuously

Operate an

ESP or FF

on

Alma Unit 4 0.030

lbs/mmBT

U [with

ESP]

0.015

lbs/mmBT

U [with FF]

at Alma 4.

Joint cap

of 112 tons

until 2019,

and 67

tons

thereafter.

In the

event that

one retires,

Tonnage

Cap of 64

tons for the

remaining

unit until

2019 and

39 tons

thereafter 12/31/14 Dairyland was provided with two

options for compliance. It chose

Option 2 and it is the one modeled

in IPM. Details on Option 1 can be

found in the settlement document

referenced in the adjoining column.

Unit 5

J.P.

Madgett Wisconsin Unit 1 Install and

continuously

operate DFGD 0.090

lbs/mmBTU 12/31/14 Continuously

Operate existing

Low NO

x Combustion

System

__

Install an SCR 0.30

lbs/mmBT

U

__

0.080

lbs/mmBT

U 8/1/2012

__

6/30/201

6 Continuously

Operate the

existing

Baghouse 0.0150

lbs/mmBT

U 07/01/13

Genoa Wisconsin Unit 1 Continuously

Operate the

FGD 0.090

lbs/mmBTU 12/31/12 Continuously

Operate existing

Low NO

x Combustion

System including

OFA

__

Install an SNCR 0.14

lbs/mmBT

U

__

Annual

Tonnage

Cap of

1,140 tons 12/31/20

14

__

6/1/2015 Continuously

Operate the

existing

Baghouse 0.0150

lbs/mmBT

U 07/01/13

Dominion Energy, Inc.

In calendar year 2014, and in each calendar year thereafter, Kincaid shall not exceed a Plant

- Wide Annual Tonnage Limitation of 3,500 tons of NO

x & 4,400 tons of SO 2 , and Brayton Point shall not

exceed a Plant

- Wide Annual Tonnage Limitation of 4,600 tons of NO

x & 4,100 tons of SO 2

.

Brayton

Point Massachuse

tts Unit 1 Continuously

Operate the

existing dry

FGD 0.150

lbs/mmBTU 06/01/13 Continuously

Operate the SCR,

OFA, and

LNB 0.080

lbs/mmBT

U 05/01/13 Install/Contin

uously

Operate a

Baghouse 0.015

lbs/mmBT

U [PM by

2013] 06/01/13 http://www2.e

pa.gov/enforc

ement/dominio

n

- energy

- inc

## 67 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Unit 2 Continuously

Operate the LNB

and OFA 0.280

lbs/mmBT

U 05/02/13 0.01

lbs/mmBT

U [PM

post

- 2013]

Unit 3 Continuously

Operate dry

FGD 0.080

lbs/mmBTU 07/01/13 Contin uously

Operate the SCR,

OFA, and

LNB 0.080

lbs/mmBT

U 05/01/13 Install/Contin

uously

Operate a

Baghouse 0.015

lbs/mmBT

U [PM by

2013]

0.01

lbs/mmBT

U [PM

post

- 2013] 07/01/13

Kincaid

Power

Station Illinois Unit 1

Continuously

Operate DSI 0.100

lbs/mmBTU 01/01/14 Continuously

Operate each

SCR and OFA 0.080

lbs/mmBT

U 05/01/13 Continuously

Operate the

ESP 0.030

lbs/mmBT

U [PM by

2013]

0.015

lbs/mmBT

U [PM by

post

- 2013] 06/01/13

Unit 2

State Line

Power

Station Indiana Unit 3

Retire 06/01/12

Unit 4

Wisconsin Power and Light

Edgewater 3

- 5

- shall not exceed an Annual Tonnage Limitation of 2,500 tons of NO

x in calendar years 2016

- 2018, and

1100 tons 2019 onwards & an Annual Tonnage Limitation of 12,500 tons of SO 2 in 2016, 6000 tons 2017

- 2018 and

1100 tons 2019 onwards. Columbia 1 & 2 shall not exceed an Annual Tonnage Limitation of 5,600 tons of NO

x in

calendar years 2016

- 2018, and 4300 tons 2019 onwards & an Annual Tonnage Limitation of 3290 tons of SO 2 in 2016

and thereafter.

Edgewater

Generating

Station Wisconsin Unit 3 Retire,

Refuel, or

Repower 12/31/15 Unit

- Specific

Annual

Tonnage

Cap of 700

Tons of SO 2 05/21/13 Unit

Specific

Annual

Tonnage

Cap of 250

tons of

NO

x 05/21/13

http://www2.e

pa.gov/enforc

ement/wiscon

sin

- power

and

- light

- et

- al

settlement Unit 4 Retire,

Refuel, or

Repower 12/31/18 0.700

lbs/mmBTU 05/21/13 Operate SNCR

and LNB 0.150

lbs/mmBT

U 01/01/14 Continuous

Operation of

the existing

ESP 0.030

lbs/mmBT

U 12/31/13

Unit 5 Install and

continuously

operate DFGD 0.075

lbs/mmBTU 12/31/16 Install and

continuously

operate SCR 0.070

lbs/mmBT

U 05/01/13 Install and

continuously

operate

Fabric Filter 0.015

lbs/mmBT

U 12/31/16

Columbia

Generating

Station Wisconsin Unit 1 Install and

continuously

operate DFGD 0.075

lbs/mmBTU 01/01/15 Operation of the

Low NO

x Combustion

System 0 .150

lbs/mmBT

U 07/21/13 Install and

continuously

operate

Fabric Filter 0.015

lbs/mmBT

U 12/31/14

## 68 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

Unit 2 0.075

lbs/mmBTU Opera tion of the

Low NO

x Combustion

System

__

Install and

continuously

operate SCR 0.150

lbs/mmBT

U

__

0.070

lbs/mmBT

U 7/21/201

3

__

12/31/20

18 0.015

lbs/mmBT

U 12/31/14

Nelson

Dewey

Generating

Station Wisconsin Unit 1 Retire,

Refuel, or

Repower 12/31/15 commence

burning 100%

Powder River

Basin or

equivalent fuel

containing ≤

1.00

lbs/mmBTU of

SO 2 0.800

lbs/mmBTU 05/22/13 0.300

lbs/mmBT

U 04/22/13 0.100 lbs/

mmBTU 04/22/13 Cease Burning Petcoke and

Commence Burning 100% PRB

Coal or

Equivalent at Nelson Dewey Units

1 and 2. Unit 2 Retire,

Refuel, or

Repower 12/31/15

Minnesota Power

Boswell Minnesota Unit 1 Retire/Repo

wer 12/31/18 FGD 0.70

lbs/mmBTU

and 0.03

lb/mmBTU

after

12/31/18 07/16/14 Continuously

Operate the ROFA

and

SNCR 0.20

lbs/mmBT

U 6/30/201

4 Continuously

Operate

Baghouses 0.015

lb/mmBTU 07/16/14

http://www2.e

pa.gov/enforc

ement/minnes

ota

- power

settlement Minnesota Unit 2 Retire/Repo

wer 12/31/18 FGD 0.70

lbs/mmBTU

and 0.03

lb/mmBTU

after

12/31/18 07/16/14 Continuously

Operate the ROFA

and

SNCR 0.20

lbs/mmBT

U 6/30/201

4 Continuously

Operate

Baghouses 0.015

lb/mmBTU 07/16/14

Minnesota Unit 3

FGD 0.030

lbs/mmBTU 12/31/18 Continuously

Operate the Low

NO

x Burners, OFA

system and SCR

control 0.060

lbs/mmBT

U 07/16/14 Continuously

Operate

Baghouses 0.015

lb/mmBTU 07/17/14

Minnesota Unit 4

FGD 0.03 05/31/16 Continuously

Operate the Low

NO

x Burners, OFA

system and SCR 0.120

lbs/mmBT

U 07/16/14 Continuously

Operate

Baghouses 0.015

lb/mmBTU 05/31/16

Taconite

Harbor Minnesota Unit 1

0.30

lbs/mmBTU 12/31/2015 Continuously

Operate the ROFA

systems and

SNCR 0.160

lbs/mmBT

U 7/16/201

4

Continuously

Operate ESP .03

lb/mmBTU 07/16/14 Minnesota Uni t 2

Minnesota Unit 3 Retire/Repo

wer/Refuelin

g 12/31/2015

Laskin Minnesota Unit 1

0.200

lb/mmBTU 07/16/14 Continuously

Operate the Low

NO

x Burners, and

OFA systems 0.190

lbs/mmBT

U 07/16/14 0.050

l b/mmBTU 07/16/14

Minnesota Unit 2

Consumer Energy

Campbell Michigan Unit 1 install and

continuously

operate DSI 0.350

lb/mmBTU

30

- Day

Rolling

Average

-------

0.290

lb/mmBTU 6/30/2016 Continuously

Operate the Low

NO

x Combustion

System

(including OFA) 0.220

lb/mmBTU

90

- Day

Rolling

Average Install and

continuously

operate

Baghouse .015

lb/mmBTU 04/01/16 http://www2.e

pa.gov/sites/pr

oduction/files/

2014

- 09/documents/

consumerener

gyco

- cd.pdf

## 69 Company

and Plant State Unit Settlement Actions

Notes Reference Retire/Repower SO 2 control NO

x Control PM or Mercury Control Allowance

Retirement Allowance

Restriction

Action Effective

Date Equipment Percent

Removal or

Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Retirement Restriction Effective

Date

90

- Day

Rolling

Average

Michigan Unit 2 install and

continuously

operate DSI 0.32

l b/mmBTU 6/30/2016 Continuously

Operate an SCR 0.080

lb/mmBTU

90

- Day

Rolling

Average Install and

continuously

operate

Baghouse .015

lb/mmBTU

Michigan Unit 3 install and

continuously

operate FGD 0.085

lb/mmBTU

30

- Day

Rolling

Average

--------

0.07

lb/mmBTU

365

- Day

Rolling

Average 12/31/2016

--------

0.07

lbs/MMBtu

after

12/31/16 Continuously

Operate an SCR 0.080

lb/mmBTU

90

- Day

Rolling

Average Install and

continuously

operate

Baghouse .015

lb/mmBTU 12/31/16

Cobb Michigan Unit 7 Retire 04/15/16 Unit will retire by 04/15/16

Michigan Unit 8 Retire 04/15/16 Unit will retire by 04/15/16

Karn Michigan Unit 1 Install and

continuously

operate FGD 0.075

lb/mmBTU 12/31/2015 Continuously

Operate the

existing SCR 0.080

lb/mmBTU 60

Ope ratin

g Days

after the

Date of

Entry Continuously

Operate the

existing

Baghouse .015

lb/mmBTU

Michigan Unit 2 Install and

continuously

operate FGD 0.075

lb/mmBTU 4/15/2016 Continuously

Operate the

existing SCR 0.080

lb/mmBTU 60

Operatin

g Days

after the

Date of

Entry Continuously

Operate the

existing

Baghouse .015

lb/mmBTU

Weadock Michigan Unit 7 Retire 04/15/16 Unit will retire by 04/15/16

Michigan Unit 8 Unit will retire by 04/15/16

Whiting Michigan Unit 1 Unit will retire by 04/15/16

Michigan Unit 2 Unit will retire by 04/15/16

Michigan Unit 3 Unit will retire by 04/15/16

## 70 Table 3

- 15 State Settlements in EPA Base Case v

. 5.1 5

Company

and Plant State Unit State Enforcement Actions

Notes Retire/Repower SO 2 Control NO

x Control PM Control Mercury Control

Action Effective

Date Equipment Percent

Removal or

Rate Effective Date Equipment Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective Date

Old AES

If the MPC project is discontinued at Greenidge Unit 4 by 12/31/2009, Unit 4 will be subject to the following SO 2 emission caps: 2005 will be 12,125 tons, 2006 will be 11,800 tons, 2007 will be 11,475 tons,

2008 will be 11,150 tons, and 2009 will be 10,825 tons. By 12/31/2009, AES shall control, repower, or cease operations at Westover Unit 7. Beginning in 2005, U nit 8 will be subject to the following SO 2 emission caps: 2005 is 9500 tons, 2006 is 9250, 2007 is 9000, 2008 is 8750, 2009 is 8500 tons. http://www.ag.ny.gov/press

release/governor

- and

- attorney

- general

announce

- new

- yorks

- largest

- coal

- plants

slash

- polluti on

Greenidge New York Unit 4 Update: as of May 2009, CONSOL and AES describe the Greenidge Unit 4 MPC effort as a success. http://investor.aes.com/phoenix.zhtml?c=

202639&p=irol

newsArticle&ID=1274075&highlight=

Install FGD 90% 09/01/07 Install SCR 0.15 09/01/07 Unit has retired

New York Unit 3 Install

BACT,

repower,

or cease

operations Install BACT 12/31/09 Install BACT 12/31/09 Unit has retired

Westover Update: as of May 2009, NO

x emissions appear to be above the specified 0.15 lbs/mmBtu http://www.powermag.com/print/environ

mental/Apply

- the

- funda mentals

- to

improve

- emissions

performance_574.html

New York Unit 8 90% 12/31/10 Install SCR 0.15 12/31/10 Unit has retired

New York Unit 7 Install

BACT,

repower,

or cease

operations Install BACT 12/31/09 Install BACT 12/31/09 Unit has retired

Hickling New York Unit 1 Install

BACT,

repower,

or cease

operations Install BACT 05/01/07 Install BACT 05/01/07 Unit has retired

New York Unit 2 Install

BACT,

repower,

or cease

operations Install BACT 05/01/07 Install BACT 05/01/07 Unit has retired

Cayuga New York Unit 1 FGD SCR Meets System

Wide RACT ESP 98%

New York Unit 2 FGD LN Concentric

Firing Meets System

Wide RACT ESP 98%

Jennison New York Unit 1 Install

BACT,

repower,

or cease

operations Install BACT 05/01/07 Install BACT 05/01/07 Unit has retired

## 71 Company

and Plant State Unit State Enforcement Actions

Notes Retire/Repower SO 2 Control NO

x Control PM Control Mercury Control

Action Effective

Date Equipment Percent

Removal or

Rate Effective Date Equipment Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective Date

New York Unit 2 Retired Install BACT 05/01/07 Install BACT 05/01/07 Unit has retired

Niagara Mohawk Power

NRG shall comply with the below annual tonnage limitations for its Huntley and Dunkirk Stations: In 2005 59,537 tons of SO 2 and 10,777 tons of NO

x , in 2006 34,230 of SO 2 and 6,772 of NO

x , in 2007

30,859 of SO 2 and 6,211 of NO

x , in 2008 22,733 tons of SO 2 and 6,211 tons of NO

x , in 2009 19,444 of SO 2 and 5,388 of NO

x , in 2010 and 2011 19,444 of SO 2 and 4,861 of NO

x , in 2012 16,807 of SO 2 and

3,241 of NO

x , 2013 and 14,169 of SO 2 and 3,241 of NO

x thereafter. http://www.ag.ny.gov/press

release/governor

- and

- attorney

- general

announce

- new

- yorks

- largest

- coal

- plants

slash

- pollution

Huntley New York Units

63

– 66 Retire Before

2008

Public Service Co. of NM

San Juan New Mexico Unit 1

State

- of

- the

- art

technology 90% 10/31/08

State

- of

- the

- art

technology 0.3 10/31/08

Operate

Baghouse and

demister

technology 0.015 12/31/09

Design

activated

carbon

injection

technology

(or

comparable

tech) 12/31/09 All four units have installed Wet

Scrubbers. Unit 1 and 4 NO

x controls

[SNCR] are hardwired into EPA Base

Case.

http://nmsierraclub.org/sites/default/files/

20055

- 10SanJuanfinaldecreeasentered%20%2

82%29.pdf

http://www.grandcanyontrust.org/media/P

DF /air/2

- 2

- 04%20Decision.pdf New Mexico Unit 2 03/31/09 03/31/09 12/31/09 12/31/09

New Mexico Unit 3 04 /30/08 04/30/08 04/30/08 04/30/08

New Mexico Unit 4 10 /31/07 10/31/07 10/31/07 10/31/07

Public Service Co of Colorado

Comanche Colorado Unit 1 Install and

operate FGD 0.1

lbs/mmBtu

combined

average 07/01/09 Install low

- NO

x emission controls

0.15 lbs/mmBtu

combined

average 07/01/09 Install

sorbent

injection

technology 07/01/09 Comanche units 1 and 2 taken together

shall not exceed a 0.15 heat rate for NO

x , nor 0.10 for SO 2

, no later than 180 days

after initial start

- up of control equipment,

or by 7/01/2009, whichever is earlier.

http://content.sierraclub.org/coal/sites/co

ntent.sierraclub.org.coal/files/elp/docs/co

- comanche_agree

- sign_2004

- 12

- 02.pdf Colorado Unit 2 Install and

operate FGD 07/01/09 Install low

- NO

x emission controls 07/01/09 Install

sorbent

injection

technology 07/01/09

Colorado Unit 3 Install and

operate FGD 0.1

lbs/mmBtu Install and operate

SCR 0.08 Install and

operate a fabric

filter dust

collection

system 0.013 Install

sorbent

injection

technology Within 180

days of start

up

Rochester Gas & Electric

Russell Plant New York Units

1

– 4 Retire all

units http://www.ag.ny.gov/press

release/cuomo

- announces

- settlement

close

- rochester

- gas

- electrics

- coal

burning

- russell

- power

Mirant New York

Lovett Plant New York Unit 1 Retire 05/07/07 http://www.nytimes.com/2007/05/11/nyre

gion/11plant.html?_r=1& pagewanted=pri

nt

New York Unit 2 Retire 04/30/08 Retirements are pursuant to a 2003

consent decree, and the plant's failure to

comply with the required reductions.

TVA

Allen Tennessee Units 1

- 3 Remove from

Service, FGD, or

Retire 12/31/2018 Install SCR Effective

Date

http://www2.epa.gov/sites/production/file

s/documents/tvacoal

- fired

- cd.pdf Bull Run Tennessee Unit 1 Install Wet FGD Effective Date Install SCR Effective

Date

Colbert Alabama Units 1

- 4 Remove from

Service, FGD,

Repower to

Renewable

Biomass, or

Retire 6/30/2016 Remove from

Service, SCR,

Repower to

Renewable

Biomass, or Retire 6/30/2016

## 72 Company

and Plant State Unit State Enforcement Actions

Notes Retire/Repower SO 2 Control NO

x Control PM Control Mercury Control

Action Effective

Date Equipment Percent

Removal or

Rate Effective Date Equipment Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective Date

Unit 5 Remove from

Service, FGD, or

Retire 12/31/2015 Install SCR Effective

Date

Cumberland Tennessee Units 1 & 2 Install Wet FGD Effective Date Install SCR Effective

Date

Gallatin Tennessee Units 1

- 4 FGD, Repower to

Renewable

Biomass, or

Retire 12/31/2017 Install SCR,

Repower to

Renewable

Biomass, or Retire 12/31/2017

John Sevier Tennessee Units 1 & 2 Retire 12/31/201

2

Units 3 & 4 Remove

from

Service 12/31/201

2 FGD, Repower to

Renewable

Biomass, or

Retire 12/31/2015 Install SCR,

Repower to

Renewable

Biomass, or Retire 12/31/2015

Johnsonville Tennessee Units 1

- 10 Retire 6 Units by

12/31/15,

4 Units by

12/31/18

Kingston Tennessee Units 1

- 9 Install Wet FGD Effective Date Install SCR Effective

Date

Paradise Kentucky Units 1 & 2 Upgrade FGD 93%

Removal 12/31/2012 Install SCR Effective

Date

Unit 3 Install Wet FGD Effective Date Install SCR Effective

Date

Shawnee Kentucky Units 1 & 4 FGD, Repower to

Renewable

Biomass, or

Retire 12/31/2017 Install SCR,

Repower to

Renewable

Biomass, or Retire 12/31/2017

Widows

Creek Alabama Units 1 & 2 Retire 7/31/2013

Unit 3 & 4 Retire 7/31/2014

Units 5 & 6 Retire 7/31/2015

Units 7 & 8 Install Wet FGD Effective Date Install SCR Effective

Date

RC Cape May Holdings, LLC

B L England New Jersey Unit 1 Retire/Rep

ower 05/01/14

http://www.nj.gov/dep/docs/20120613104

728.pdf

Unit 2 Retire/Rep

ower 05/01/17 FGD SNCR & OFA 0.42 lb/ mmBtu

## 73 Table 3

- 16 Citizen Settlements in EPA Base Case v.5.1 5

Company and

Plant State Unit Citizen Suits Provided by DOJ

Notes Retire/Repower SO 2 control NO

x Control PM Control Mercury Control

Action Effective

Date Equipment Percent Removal

or Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date

SWEPCO (AEP)

Welsh Texas Units

1

- 3 Install and

operate CEMs 12/31/2010 SWEPCO may attempt to demonstrate that PM

CEMs are infeasible after two years of operation.

http://www.ocefoundation.org/PDFs/ConsentDecr

ee&CLtoDOJ.pdf

Allegheny Energy

Hatfield's Ferry Pennsylvania Unit 1

Install and

operate

wet FGD 6/30/2010 Install and

operate sulfur

trioxide injection

systems, improve

ESP

performance 0.1 lbs/mmBtu in

2006, then 0.075

lbs per hour

(filterable) and 0.1

lbs/mmBtu for

particles less than

ten microns in

2010 7/31/2006

and

6/30/2010 http://www.environmentalintegrity.org/law_library/

PennFuture_EIP_Lawsuit.php Pennsylvania Unit 2

Pennsylvania Unit 3 11/31/2006

and

6/30/2010

Wisconsin Public Service Corp

Pulliam Wisconsin Unit 3

Retire 12/31/2007 http://milwaukee.bizjournals.com/milwaukee/stori

es/2006/10/23/daily29.html Wisconsin Unit 4

University of Wisconsin

Charter Street

Heating Plant Wisconsin Repower to

burn 100%

biomass 12/31/2012 Sierra Club suit was based on NSR.

http://wisconsin.sierraclub.org/PDF/press/112607

_PR_WIStateOwnedCoalSettlement.pdf

Tucson Electric Power

Springerville

Plant Arizona Unit 1

Dry FGD,

85%

reduction

required 0.27 lbs/ mmBtu 12/31/2006

SCR, LNB 0.22 lbs/mmBtu 12/31/2006

Baghouse 0.03 lbs/mmBtu 1/1/2006

Lawsuit filed by Grand Canyon Trust. Consent

decree is not published. For the compliance

details, see the EPA's own copy of the plant's

permit revisions:

http://xrl.us/springerville and

http://xrl.us/springerville2 Arizona Unit 2

Arizona Unit 3

Arizona Unit 4 Four

- unit cap of

10,662 tons per

year once units 3

and 4 are

operational Four

- unit cap of

8,940 tons per

year once units

3 and 4 are

operational

Kansas City Board of Public Utilities

Quindaro Kansas Units 1 Cease burning

coal/Convert to

natural gas 04/16/15

http://www.bpu.com/AboutBPU/MediaNewsRelea

ses/BPUUnifiedGovernmentSettleThreatenedLaw

suit.aspx

http://www.platts.com/RSSFeedDetailedNews/RS

SFeed/E lectricPower/21193551

"end coal

- fired operations at two coal units

totaling 167 MW at its Quindaro station by April

2015 and to install a baghouse at its 232

- MW

Nearman

- 1 coal unit by September 2017."

"BPU spokesman David Mehlhaff said the muni

plans to co nvert the Quindaro

- 1 and

- 2 coal units

to only natural gas firing, probably by April 2015;

both units currently have dual

- fuel capabilities." Kansas Units 2

Nearman Kansas Unit 1 Install and

continuously

operate a

baghouse 0.01 lbs/mmBtu 09/01/17

## 74 Company and

Plant State Unit Citizen Suits Provided by DOJ

Notes Retire/Repower SO 2 control NO

x Control PM Control Mercury Control

Action Effective

Date Equipment Percent Removal

or Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date Equipment Rate Effective

Date

MidAmerican Energy Company

Walter Scott, Jr

Energy Center Iowa Units 1

Cease burning

coal/Convert to

natural gas 04/16/16 http://www.sec.gov/Archives/edgar/data/928576/0

00092857613000014/llcmec33113form10

- q.htm

"MidAmerican Energy has committed to cease

burning solid fuel, such as coal, at its Walter

Scott, Jr. Energy Center Units 1

and 2, George Neal Energy Center Units 1 and 2

and Riverside Energy Center by April 16,

2016...The George Neal Energy Center Unit 1

and Riverside Energy Center currently have the

capability to bu rn natural gas in the production of

electricity, although under current operating and

economic conditions, production utilizing natural

gas would be very limited" Iowa Units 2

George Neal

Energy Center Iowa Units 1

Iowa Units 2

Riverside

Energy Center Iowa Units 7

Iowa Units 8

Iowa Units 9

Dominion Energy

Salem Harbor Massachusetts Unit 1

-

4 Retire 12/31/2011

for units

1&2

6/1/2014

for units

3&4 http://www.clf.org/wp

content/uploads/2012/02/Signed

- Consent

Decree

- 12_11.pdf

Duke Energy

Wabash River Indiana Unit 2

-

5 Retire 2014

http://www.duke

- energy.com/about

- us/retired

coal

- units

- potential

- retirements.asp

Wabash River Indiana Unit 6 Coal to Gas

Conversion 6/12018

KCPL

La Cygne Kansas Units 1

0.1 lbs/MMBtu 2015 0.13 lbs/MMBtu 2015

Units 2

## 75 Table 3

- 17 Renewable Portfolio Standards in EPA Base Case v

. 5.1 5

Regional Renewable Portfolio Standards

- AEO 2013

NEMS Region IPM Regions Covered Unit

s 2016 2018 2020 2025 2030

-

2050

ERCOT (1) ERC_REST, ERC_FRNT, ERC_GWAY, ERC_WEST % 4.5% 4.5% 4.4% 4.4% 4.4%

MROE (3) MIS_WUMS (42%) % 10.1% 10.0% 10.0% 9.9% 10.0%

MROW (4) MAP_WAUE, MIS_IA, MIS_MIDA, MIS_MNWI, MIS_MAPP, SPP_NEBR % 8.9% 9.6% 10.3% 11.3% 11.4%

NEWE (5) NENG_CT, NENGREST, NENG_ME % 11.6% 13.0% 14.3% 14.5% 14.6%

NYCW (6), NYLI (7),

NYUP (8) NY_Z_J, NY_Z_K, NY_Z_C&E, NY_Z_F, NY_Z_G

- I, NY_Z_A&B % 25.0% 24.8% 24.6% 24.5% 24.6%

RFCE (9) PJM_EMAC, PJM_PENE, PJM_SMAC, PJM_WMAC % 9.7% 11.6% 13.6% 14.7% 14.8%

RFCM (10) MIS_LMI % 10.1% 10.1% 10.0% 9.9% 10.0%

RFCW (11) MIS_INKY (90%), MIS_WUMS (58%), PJM_West, PJM_AP, PJM_ATSI,

PJM_COMD % 5.0% 6.0% 7.1% 9.2% 9.3%

SRDA (12) S_D_AMSO, S_D_N_AR, S_D_REST, S_D_WOTA, SPP_WEST (10%) % 0.7% 0.6% 0.6% 0.6% 0.6%

SRGW (13) MIS_IL, MIS_MO, SPP_N (3%) % 7.3% 10.2% 11.2% 15.7% 15.8%

SRCE (15) S_C_KY, S_C_TVA, MIS_INKY (10%) % 0.0% 0.0% 0.0% 0.1% 0.1%

SRVC (16) PJM_Dom, S_VACA % 3.3% 4.2% 5.0% 5.5% 5.5%

SPNO (17) SPP_N (97%) % 8.5% 9.7% 11.9% 13.1% 13.2%

SPSO (18) SPP_SE, SPP_SPS, SPP_WEST (90%), SPP_KIAM % 1.8% 1.9% 2.1% 2.2% 2.2%

AZNM (19) WECC_AZ, WECC_IID, WECC_NM, WECC_SNV % 7.4% 8.0% 9.4% 11.1% 11.1%

CAMX (20) WEC_LADW, WEC_CALN, WEC_SDGE, WECC_SF, WECC_SCE % 25.6% 29.3% 33.0% 32.9% 33.0%

NWPP (21) WECC_ID, WECC_MT, WECC_NNV, WECC_PNW, WECC_UT,

WECC_WY (58%) % 7.2% 7.2% 10.1% 10.9% 11.0%

RMPA (22) WECC_CO, WECC_WY (42%) % 16.8% 20.1% 23.3% 23.1% 23.36%

Regional RPS Solar Carve

- outs

NEMS Region IPM Regions Covered Unit

s 2016 2018 2020 2025 2030

-

2050

ERCOT (1) ERC_REST, ERC_FRNT, ERC_GWAY, ERC_WEST %

- - - - - MROE (3) MIS_WUMS (42%) %

- - - - - MROW (4) MAP_WAUE, MIS_IA, MIS_MIDA, MIS_MNWI, MIS_MAPP, SPP_NEBR % 0.01% 0.01% 0.58% 0.58% 0.59%

NEWE (5) NENG_CT, NENGREST, NENG_ME % 0.08% 0.08% 0.08% 0.08% 0.08%

NYCW (6), NYLI (7),

NYUP (8) NY_Z_J, NY_Z_K, NY_Z_C&E, NY_Z_F, NY_Z_G

- I, NY_Z_A&B % 0.00% 0.00% 0.00% 0.00% 0.00%

RFCE (9) PJM_EMAC, PJM_PENE, PJM_SMAC, PJM_WMAC % 0.30% 0.49% 0.67% 0.71% 0.71%

RFCM (10) MIS_LMI %

- - - - -

RFCW (11) MIS_INKY (90%), MIS_WUMS (58%), PJM_West, PJM_AP, PJM_ATSI,

PJM_COMD % 0.18% 0.25% 0.32% 0.43% 0.45%

## 76 Regional RPS Solar Carve

- outs

NEMS Region IPM Regions Covered Unit

s 2016 2018 2020 2025 2030

-

2050

SRDA (12) S_D_AMSO, S_D_N_AR, S_D_REST, S_D_WOTA, SPP_WEST (10%) %

- - - - - SRGW (13) MIS_IL, MIS_MO, SPP_N (3%) % 0.29% 0.39% 0.46% 0.68% 0.72%

SRCE (15) S_C_KY, S_C_TVA, MIS_INKY (10%) % 0.001% 0.001

% 0.001

% 0.001

% 0.001%

SRVC (16) PJM_Dom, S_VACA % 0.06% 0.09% 0.09% 0.09% 0.09%

SPNO (17) SPP_N (97%) % 0.03% 0.05% 0.05% 0.08% 0.08%

SPSO (18) SPP_SE, SPP_SPS, SPP_WEST (90%), SPP_KIAM % 0.10% 0.10% 0.14% 0.14% 0.14%

AZNM (19) WECC_AZ, WECC_IID, WECC_NM, WECC_SNV % 0.48% 0.47% 0.58% 0.60% 0.61%

CAMX (20) WEC_LADW, WEC_CALN, WEC_SDGE, WECC_SF, WECC_SCE %

- - - - -

NWPP (21) WECC_ID, WECC_MT, WECC_NNV, WECC_PNW, WECC_UT,

WECC_WY (58%) % 0.05% 0.05% 0.06% 0.06% 0.06%

RMPA (22) WECC_CO, WECC_WY (42%) % 0.01% 0.01% 0.02% 0.02% 0.02%

Notes:

The Renewable Portfolio Standard percentages are applied to modeled electricity sale projections.

Waste Coal plants in Pennsylvania are included in the appropriate RPS constraints.

The Solar Carve

- out constraints only apply to units from the following states: DC, IL, MA, MD, MN, MO, NC, NH, NM, NV, OH, PA

## 77 Table 3

- 19 BART Regulations included in EPA Base Case v.5.1 5

BART Affected Plants UniqueID BART Status / CSAPR /

Shutdown/ Coal

- to

- Gas NO

x BART

Limit SO 2 BART

Limit NO

x Compliance

Date SO 2 Compliance

Date

Colstrip 6076_B_1 BART NO

x 0.15 lb/MMBtu 2018 2018

Colstrip 6076_B_2 BART NO

x 0.15 lb/MMBtu 2018 2018

Comanche 470_B_1 BART NO

x 0.20 lb/MMBtu 2018 2018

Comanche 470_B_2 BART NO

x 0.20 lb/MMBtu 2018 2018

Craig 6021_B_C1 BART NO

x & BART SO 2 0. 0 7 lb/MMBtu 0. 11

lb/MMBtu 20 21 2018

Craig 6021_B_C2 BART NO

x & BART SO 2 0.08 lb/MMBtu 0. 11

lb/MMBtu 2018 2018

Four Corners 2442_B_1 BART NO

x : Shut down

by 2013 0.05 lb/MMBtu Actual

emissions 2018 2018

Four Corners 2442_B_2 BART NO

x : Shut down

by 2013 0.05 lb/MMBtu Actual

emissions 2018 2018

Four Corners 2442_B_3 BART NO

x : Shut down

by 2013 0.05 lb/MMBtu Actual

emissions 2018 2018

Four Corners 2442_B_4 BART NO

x 0.0 98 lb/MMBtu Actual

emissions 2018 2018

Four Corners 2442_B_5 BART NO

x 0.05 lb/MMBtu Actual

emissions 2018 2018

Gerald Gentleman 6077_B_1 BART NO

x 0.23 lb/MMBtu TBD 2018 2018

Gerald Gentleman 6077_B_2 BART NO

x 0.23 lb/MMBtu TBD 2018 2018

Hayden 525_B_H1 BART NO

x 0.08 lb/MMBtu 2018 2018

Hayden 525_B_H2 BART NO

x 0.07 lb/MMBtu 2018 2018

J E Corette Plant 2187_B_2 BART NO

x 0.35 lb/MMBtu 2018 2018

Martin Drake 492_B_5 BART NO

x 0.31 lb/MMBtu 2018 2018

Martin Drake 492_B_6 BART NO

x 0.32 lb/MMBtu 2018 2018

Martin Drake 492_B_7 BART NO

x 0.32 lb/MMBtu 2018 2018

Nebraska City 6096_B_1 BART NO

x 0.23 lb/MMBtu 2018 2018

Reid Gardner 2324_B_1 BART NO

x 0.20 lb/MMBtu 2018 2018

Reid Gardner 2324_B_2 BART NO

x 0.20 lb/MMBtu 2018 2018

Reid Gardner 2324_B_3 BART NO

x 0.20 lb/MMBtu 2018 2018

San Juan 2451_B_1 BART NO

x 0.11 lb/MMBtu Actual

emissions 2018 2018

San Juan 2451_B_2 BART NO

x 0.11 lb/MMBtu Actual

emissions 2018 2018

San Juan 2451_B_3 BART NO

x 0.11 lb/MMBtu Actual

emissions 2018 2018

San Juan 2451_B_4 BART NO

x 0.11 lb/MMBtu Actual

emissions 2018 2018

Tecumseh Energy Center 1252_B_10 BART NO

x 0.18 lb/MMBtu 2018 2018

Apache Station 160_B_2 BART NO

x & BART SO 2 0.07 lb/MMBtu

across 2 units 0.15

lb/MMBtu 12/1/17 12/1/16

Apache Station 160_B_3 BART NO

x & BART SO 2 0.07 lb/MMBtu

across 2 units 0.15

lb/MMBtu 12/1/17 12/1/16

Cherokee 469_B_4 BART NO

x & BART SO 2 0.12 lb/MMBtu 7.81 tpy

(12 month

rolling) 2018 2018

Cholla 113_B_2 BART NO

x & BART SO 2 0.055 lb/MMBtu

across 3 units 0.15

lb/MMBtu 12/1/17 12/5/13

Cholla 113_B_3 BART NO

x & BART SO 2 0.055 lb/MMBtu

across 3 units 0.15

lb/MMBtu 12/1/17 12/5/13

Cholla 113_B_4 BART NO

x & BART SO 2 0.055 lb/MMBtu

across 3 units 0.15

lb/MMBtu 12/1/17 12/5/13

Coal Creek 6030_B_1 BART NO

x & BART SO 2 0.13 lb/MMBtu

(combined both

units) 0.15

lb/MMBtu

or 95%

efficiency 2018 2018

Coal Creek 6030_B_2 BART NO

x & BART SO 2 0.13 lb/MMBtu

(combined both

units) 0.15

lb/MMBtu

or 95%

efficiency 2018 2018

Coronado 6177_B_U1B BART NO

x & BART SO 2 0.065 lb/MMBtu

across 2 units 0.08

lb/MMBtu 12/1/17 6/5/13

## 78 BART Affected Plants UniqueID BART Status / CSAPR /

Shutdown/ Coal

- to

- Gas NO

x BART

Limit SO 2 BART

Limit NO

x Compliance

Date SO 2 Compliance

Date

Coronado 6177_B_U2B BART NO

x & BART SO 2 0.065 lb/MMBtu

across 2 units 0.08

lb/MMBtu 12/1/17 6/5/13

Jeffrey Energy Center 6068_B_1 BART NO

x & BART SO 2 0.15 lb/MMBtu 0.15

lb/MMBtu 2018 2018

Jeffrey Energy Center 6068_B_2 BART NO

x & BART SO 2 0.15 lb/MMBtu 0.15

lb/MMBtu 2018 2018

La Cygne 1241_B_1 BART NO

x & BART SO 2 0.13 lb/MMBtu

(combined both

units) 0.15

lb/MMBtu 6/1/15 6/1/15

La Cygne 1241_B_2 BART NO

x & BART SO 2 0.13 lb/MMBtu

(combined both

units) 0.15

lb/MMBtu 6/1/15 6/1/15

Leland Olds 2817_B_1 BART NO

x & BART SO 2 0.19 lb/MMBtu 0.15

lb/MMBtu

or 95%

efficiency 2018 2018

Leland Olds 2817_B_2 BART NO

x & BART SO 2 0.35 lb/MMBtu 0.15

lb/MMBtu

or 95%

efficiency 2018 2018

Merrimack 2364_B_2 BART NO

x & BART SO 2 0.30 lb/MMBtu 90 %

control 2018 2018

Milton R Young 2823_B_B1 BART NO

x & BART SO 2 0.36 lb/MMBtu 0.15

lb/MMBtu

or 95%

efficiency 2018 2018

Milton R Young 2823_B_B2 BART NO

x & BART SO 2 0.35 lb/MMBtu 0.15

lb/MMBtu

or 95%

efficiency 2018 2018

Muskogee 2952_B_4 BART NO

x & BART SO 2 0.15 lb/MMBtu 0.06

lbs/MMBtu 2018 2018

Muskogee 2952_B_5 BART NO

x & BART SO 2 0.15 lb/MMBtu 0.06

lbs/MMBtu 2018 2018

Pawnee 6248_B_1 BART NO

x & BART SO 2 0.07 lb/MMBtu 0.12

lb/MMBtu 2018 2018

Ray D Nixon 8219_B_1 BART NO

x & BART SO 2 0.21 lb/MMBtu 0.11

lb/MMBtu 2018 2018

Sooner 6095_B_1 BART NO

x & BART SO 2 0.15 lb/MMBtu 0.06

lbs/MMBtu 2018 2018

Sooner 6095_B_2 BART NO

x & BART SO 2 0.15 lb/MMBtu 0.06

lbs/MMBtu 2018 2018

Stanton 2824_B_1 BART NO

x & BART SO 2 0.29 lb/MMBtu 0.24

lb/MMBtu 2018 2018

Lansing Smith 643_B_1 BART NO

x & BART SO 2 4700 tpy across

2 units 0.74

lb/MMBtu 2018 2018

Lansing Smith 643_B_2 BART NO

x & BART SO 2 4700 tpy across

2 units 0.74

lb/MMBtu 2018 2018

Northeastern 2963_B_3313 BART NO

x & BART SO 2 ; Shut down by 2016 0.23 lb/MMBtu 0.60

lb/MMBtu 2018 2018

Boardman 6106_B_1SG BART NO

x & BART SO 2 ; Shut down by 2020 0.7 lb/MMBtu 1.2

lb/MMBtu 2018 2018

Northeastern 2963_B_3314 BART NO

x & BART SO 2 ; Shut down by 2024 0.15 lb/MMBtu 0.40

lb/MMBtu 2018 2018

Seminole 136_B_1 BART SO 2 0.25

lb/MMBtu 2018 2018

Seminole 136_B_2 BART SO 2 0.25

lb/MMBtu 2018 2018

Northside Generating Station 667_B_1 BART SO 2 3600 tpy

across 3

units 2018 2018

Northside Generating Station 667_B_2 BART SO 2 3600 tpy

across 3

units 2018 2018

Northside Generating Station 667_B_3 BART SO 2 3600 tpy

across 3

units 2018 2018

Deerhaven Generating Station 663_B_B2 BART SO 2 5500 tpy 2018 2018

Merrimack 2364_B_2 BART SO 2 Actual

Emissions

[with FGD] 2018 2018

Yates 728_B_Y6BR Coal

- to

- Gas by 2016

## 79 BART Affected Plants UniqueID BART Status / CSAPR /

Shutdown/ Coal

- to

- Gas NO

x BART

Limit SO 2 BART

Limit NO

x Compliance

Date SO 2 Compliance

Date

Yates 728_B_Y7BR Coal

- to

- Gas by 2016

George Neal North 1091_B_1 Coal

- to

- Gas by

4/16/2016

George Neal North 1091_B_2 Coal

- to

- Gas by

4/16/2016

George Neal North 1091_B_3 Coal

- to

- Gas by

4/16/2016

Walter Scott Jr. Energy Center 1082_B_3 Coal

- to

- Gas by

4/16/2016

Big Cajun 2 6055_B_2B1 BART NO

x : Convert to

NG by 4/15/2015 0.15 lb/MMBtu 2014

J H Campbell 1710_B_ 1 BART SO 2 0.29

lb/MMBtu 2017

J H Campbell 1710_B_2 BART NO

x & BART SO 2 0.08 lb/MMBtu 0.32

lb/MMBtu 2015 2017

J H Campbell 1710_B_3 BART NO

x & BART SO 2 0.08 lb/MMBtu 0.07

lb/MMBtu 2015 2018

Tecumseh Energy Center 1252_B_9 BART NO

x 0.1 8 lb/MMBtu 2018

Lawrence Energy Center 1250_B_3 BART NO

x 0.1 8 lb/MMBtu 2014

Lawrence Energy Center 1250_B_4 BART NO

x & BART SO 2 0.1 8 lb/MMBtu 0.1 5

lb/MMBtu 2014 2014

Lawrence Energy Center 1250_B_5 BART NO

x & BART SO 2 0.1 5 lb/MMBtu 0.1 5

lb/MMBtu 2014 2014

Laramie River Station 6204_B_3 BART NO

x 0.07 lb/MMBtu 2018

Lee 2709_B_3 Shut down by 2013

L V Sutton 2713_B_3 Shut down by 2017

Portland 3113_B_2 Shut down by 1/7/2015

Harllee Branch 709_B_2 Shut down by 10/1/13

Canadys Steam 3280_B_CAN1 Shut down by 12/1/2017

Canadys Steam 3280_B_CAN2 Shut down by 12/1/2017

Canadys Steam 3280_B_CAN3 Shut down by 12/1/2017

Harllee Branch 709_B_1 Shut down by 12/31/13

Chesapeake 3803_B_4 Shut down by 12/31/14

Welsh 6139_B_2 Shut down by 12/31/14

Conesville 2840_B_3 Shut down by

12/31/2012

HMP&L Station Two Henderson 1382_B_H1 Shut down by 2008

Menasha 4127_B_B24 Shut down by 2009

Pella 1175_B_6 Shut down by 2012

Pella 1175_B_7 Shut down by 2012

Jefferies 3319_B_3 Shut down by 2013

Jefferies 3319_B_4 Shut down by 2013

Big Sandy 1353_B_BSU2 Shut down by 2015

Frank E Ratts 1043_B_1SG1 Shut down by 2015

Frank E Ratts 1043_B_2SG1 Shut down by 2015

Harbor Beach 1731_B_1 Shut down by 2015

Nelson Dewey 4054_B_2 Shut down by 2015

Cane Run 1363_B_4 Shut down by 2016

Cane Run 1363_B_5 Shut down by 2016

Cane Run 1363_B_6 Shut down by 2016

Harllee Branch 709_B_3 Shut down by 2016

Harllee Branch 709_B_4 Shut down by 2016

Kraft 733_B_3 Shut down by 2016

J T Deely 6181_B_1 Shut down by 2018

J T Deely 6181_B_2 Shut down by 2018

State Line 981_B_4 Shut down by 3/25/12

Avon Lake 2836_B_12 Shut down by 4/1/2015

## 80 BART Affected Plants UniqueID BART Status / CSAPR /

Shutdown/ Coal

- to

- Gas NO

x BART

Limit SO 2 BART

Limit NO

x Compliance

Date SO 2 Compliance

Date

Walter C Beckjord 2830_B_5 Shut down by 4/1/2015

Walter C Beckjord 2830_B_6 Shut down by 4/1/2015

New Castle 3138_B_5 Shut down by 4/16/2015

Big Sandy 1353_B_BSU1 Shut down by 6/1/2015

Bay Shore 2878_B_3 Shut down by 9/1/2012

Bay Shore 2878_B_4 Shut down by 9/1/2012

Eastlake 2837_B_5 Shut down by 9/1/2012

Edgewater 4050_B_4 Shutdown or Coal

- to

Gas by 12/31/2018

Dave Johnston 4158_B_BW43 BART NO

x Shut down by 2027 0.28 lb/MMBtu 2018

Dave Johnston 4158_B_BW44 BART NO

x 0.15 lb/MMBtu 2018

Jim Bridger 8066_B_BW71 BART NO

x 0.26 lb/MMBtu 2018

Jim Bridger 8066_B_BW72 BART NO

x 0.26 lb/MMBtu 2018

Jim Bridger 8066_B_BW73 BART NO

x 0.26 lb/MMBtu 2018

Jim Bridger 8066_B_BW74 BART NO

x 0.26 lb/MMBtu 2018

Laramie River Station 6204_B_1 BART NO

x 0.07 lb/MMBtu 2018

Laramie River Station 6204_B_2 BART NO

x 0.07 lb/MMBtu 2018

Naughton 4162_B_1 BART NO

x 0.26 lb/MMBtu 2018

Naughton 4162_B_2 BART NO

x 0.26 lb/MMBtu 2018

Naughton 4162_B_3 BART NO

x Convert to NG by 2018 0.07 lb/MMBtu 2018

Wyodak 6101_B_BW91 BART NO

x 0.07 lb/MMBtu 2018

Navajo 4941_B_1 Shut down by 12/31/19

Navajo 4941_B_2 BART NO

x 0.07 lb/MMBtu 2030

Navajo 4941_B_3 BART NO

x 0.07 lb/MMBtu 2030

Indian River Generating Station 594_B_3 Shut down by 12/31/13

Cherokee 469_B_3 Shut down by 12/31/16

Valmont 477_B_5 Shut down by 12/31/17

Crystal River 628_B_1 Shut down by 2020

Crystal River 628_B_2 Shut down by 2020

Transalta Centralia Generation 3845_B_BW21 Shut down by 2020

Transalta Centralia Generation 3845_B_BW22 Shut down by 2025

Lansing Smith 643_B_1 BART NO

x 4700 tpy across

2 units 2018

Lansing Smith 643_B_2 BART NO

x 4700 tpy across

2 units 2018

## 81 Table 4

- 1 Data Sources for NEEDS v.5.1 5 for EPA Base Case v.5.1 5

Data Source 1 

## Data Source Documentation

DOE's Form EIA

- 860 DOE's Form EIA

- 860 is an annual survey of utility and non

- utility power plants at the generator

level. It contains data such as summer, winter and nameplate capacity, location (state and county),

operating status, prime mover, energy sources and in

- service date of existing and proposed

generators. NEEDS v .5.1 5 uses EIA Form 860 (2010, 2011, and 2012) data as one of the primary

generator data inputs.

DOE's Form EIA

- 860 also collects data of steam boilers such as energy sources, boiler

identification, location, operating status and design information; and associated environmental

equipment such as NO

x 

## combustion and post

- combustion control, FGD scrubber, mercury control

and particulate collector device information. Note that boilers in plants with less than 10 MW do not

report all data elements. The associ ation between boilers and generators is also provided. Note that

boilers and generators are not necessarily in a one

- to

- one correspondence. NEEDS v.5.1 5 uses

EIA Form 860 (2010, 2011, and 2012) data as one of the primary boiler data inputs.

NERC Electricity

Supply and Demand

(ES&D) database The NERC ES&D is released annually. It contains generator

- level information such as summer,

winter and nameplate capacity, state, NERC region and sub

- region, status, primary fuel and on

- line

year. NEEDS v.5.1 5 uses NERC ES&D (2011) data as one of the data inputs.

DOE’s Annual Energy

Outlook (AEO) The Energy Information Administration (EIA) Annual Energy Outlook presents annually updated

forecasts of energy supply, demand and prices covering a 20

- 25 year time horizon. The projections

are based on results from EIA’s National Energy Modeling System (NEMS). Information from AEO

2012 such as heat rates, planned committed units were used in NEEDS v.5.1 5 . Nuclear unit

capacities and uprates are from AEO 201 5

.

Ventyx's New

Entrants database Ventyx's New Entrants database has information on new power plant builds, rerates and

retirements. NEEDS v.5.1 5 uses the dataset downloaded on April 13, 2012 and April 23, 2013, as

one of the sources of development of committ ed generating units.

SNL Energy

Database SNL Energy tracks electric power development projects in North America. NEEDS v.5.1 5 uses the

dataset downloaded on August 11, 2014, as one of the sources of developing committed generating

units.

EPA's Emission

Tracking System The Emission Tracking System (ETS) database is updated quarterly. It contains boiler

- level

information such as primary fuel, heat input, SO 2 

## and NO

x 

## controls, and SO 2 

## and NO

x 

## emissions.

NEEDS v.5.1 5 uses annual and seasonal ETS (2011) data as one of the primary data inputs for

NO

x 

## rate development and environmental equipment assignment.

Utility and Regional

EPA Office

Comments Comments from utilities and regional EPA offices regarding the population in NEEDS (retirements,

new units) as well as unit characteristics were incorporated in NEEDS v.5.1 5

.

1 

## Shown in Table 4

- 1 are the primary issue dates of the indicated data sources that were used. Other vintages of these

data sources were also used in instances where data were not available for the indicated issued date or where there were

methodological reasons for using other vintages of the data.

## 82 Table 4

- 2 Rules Used in Populating NEEDS v.5.1 5 for EPA Base Case v.5.1 5

Scope Rule

Capacity Excluded units with reported summer capacity, winter capacity and

nameplate capacity of zero or blank.

Status Excluded units that were out of service for two or three consecutive years

(i.e., generators with status codes “OS” in the latest three reporting years

and boilers with status codes “OS” in the latest two reporting years) and units

that were no longer in service and not expected to be returned to service

(i.e., generators or boilers with status codes of "RE"). Status of boiler(s) and

associated generator(s) were taken into account for determining operation

status

Planned or Committed

Units Included planned units that had broken ground , Such planned units are

generally expected to be online by the end of 2015 . However, the cut

- off

year could be extended into 2018 for large combined cycle, hydro, or nuclear

projects as long as these projects have initiated construction.

Firm/Non

- firm Electric

Sales Excluded non

- utility onsite generators that do not produce electricity for sale

to the grid on a net basis

Excluded all mobile and distributed generators



## Table 4

‐ 3 Summary Population (through 2012) of Existing Units in NEEDS v.5.1 5 for EPA Base

Case v.5.1 5

Plant Type Number of

Units Capacity (MW)

Biomass 162 3,288

Coal Steam 926 280,262

Combined Cycle 1738 217,020

Combustion Turbine 5409 137,886

Fossil Waste 60 419

Fuel Cell 50 45

Geothermal 166 2,373

Hydro 3754 77,579

IGCC 9 1,125

Landfill Gas 1431 1,684

Municipal Solid Waste 175 2,164

Non

- Fossil Waste 128 1,478

Nuclear 99 98,008

O/G steam 485 88,867

Pumped Storage 153 22,352

Solar PV 571 2,833

Solar Thermal 16 805

Tires 2 46

Wind 928 59,459

US Total 16,262 997,692

## 83 Table 4

- 4 Hierarchy of Data Sources for Capacity in NEEDS v.5.1 5

Sources Presented in Hierarchy

Summer Net Dependable Capacity from Comments

2010 EIA 860 Summer Capacity

2011 EIA 860 Summer Capacity

2012 EIA 860 Summer Capacity

2010 EIA 860 Winter Capacity

2011 EIA 860 Winter Capacity

2012 EIA 860 Winter Capacity

2010 EIA 860 Nameplate Capacity

2011 EIA 860 Nameplate Capacity

2012 EIA 860 Nameplate Capacity

Notes :

Presented in hierarchical order that applies.

Table 4

- 6 Data Sources for Unit Configuration in NEEDS v.5.1 5 for EPA Base Case v.5.1 5

Unit

Component Primary Data Source Secondary Data

Source Tertiary

Data

Source Other

Sources Default

Firing Type 2010 EIA 860 EPA’s Emission

Tracking System

(ETS)

– 2011 -- -- --

Bottom Type 2010 EIA 860 EPA’s Emission

Tracking System

(ETS)

– 2011 -- -- Dry

SO 2 

### Pollution

Control NSR Settlement or

Comments EPA’s Emission

Tracking System

(ETS)

- 2011 2010 EIA

860 See Note No

Control

NO

x 

### Pollution

Control NSR Settlement or

Comments EPA’s Emission

Tracking System

(ETS)

- 2011 2010 EIA

860 See Note No

Control

Mercury Control NSR Settlement or

Comments 2010 EIA 860

-- -- No

Control

Particulate

Matter Control NSR Settlement or

Comments EPA’s Emission

Tracking System

(ETS)

- 2011 2010 EIA

860 -- No

Control

HCl Control NSR Settlement or

Comments -- -- See Note No

Control

Note:

In addition to the primary, secondary and tertiary data sources listed here, the following sources were consulted and

emission controls were updated when corroborating information could be found: Reports filed with the Securities and

Exchange Commission; w ebsites of generating unit owners and operators; GenerationHub; state public utility service

commissions; state permitting agencies; architecture and engineering firm announcements (eg.: Shaw, URS, Stanley,

Black &Veatch, Peter Kewit, etc.); equipment sup plier announcements (Alstom, B&W, Babcock Power); Power

Eng.com; McILVAINE Utility Upgrade Database; ICAC (Institute of Clean Air Companies). Furthermore, comments

received on prior versions of NEEDS on firing type, bottom type and emission controls are reviewed and incorporated

in NEEDS v.5.14.

## 84 Table 4

‐ 7 Aggregation Profile of Model Plants as Provided at Set Up of EPA Base Case v.5.1 5

Existing and Planned/Committed Units

Plant Type Number of Units Number of IPM Model Plants

Biomass 203 133

Coal Steam 937 732

Combined Cycle 1829 823

Combustion Turbine 5551 2258

Fossil Other 61 19

Fuel Cell 71 29

Geothermal 184 30

Hydro 3814 186

Import 1 1

Integrated Gas Combined Cycle 12 5

Landfill Gas 1537 280

Non Fossil Other 350 166

Nuclear 104 104

Oil/Gas Steam 494 330

Pumped Storage 153 24

Solar PV 1059 98

Solar Thermal 32 11

Wind 1072 120

Total 17,464 5,349

New Units

Plant Type Number of Units Number of IPM Model Plants

New Advanced Coal with CCS

-- 176

New Biomass

-- 123

New Combined Cycle

-- 200

New Combined Cycle with Carbon Capture

-- 200

New Combustion Turbine

-- 200

New Energy Efficiency

-- 896

New Fuel Cell

-- 122

New Future Technology

-- 305

New Geothermal

-- 64

New IGCC

-- 186

New Landfill Gas

-- 369

New Nuclear

-- 400

New Offshore Wind

-- 714

New Onshore Wind

-- 1480

New Solar PV

-- 228

New Solar Thermal

-- 91

New SPC

- WetFGD_SCR

-- 176

Total

-- 5,930

## 85 Retrofits

Plant Type Number of Units Number of IPM Model

Plants

Retrofit Coal with ACI

-- 334

Retrofit Coal with ACI + CCS

-- 142

Retrofit Coal with ACI + CCS + HRI

-- 142

Retrofit Coal with ACI + CCS + HRI + SCR

-- 62

Retrofit Coal with ACI + CCS + HRI + SCR + Scrubber

-- 96

Retrofit Coal with ACI + CCS + HRI + Scrubber

-- 118

Retrofit Coal with ACI + CCS + HRI + SNCR

-- 1

Retrofit Coal with ACI + CCS + SCR

-- 62

Retrofit Coal with ACI + CCS + SCR + Scrubber

-- 96

Retrofit Coal with ACI + CCS + Scrubber

-- 118

Retrofit Coal with ACI + CCS + SNCR

-- 10

Retrofit Coal with ACI + DSI

-- 293

Retrofit Coal with ACI + DSI + HRI

-- 293

Retrofit Coal with ACI + DSI + HRI + SCR

-- 393

Retrofit Coal with ACI + DSI + HRI + SCR + Scrubber

-- 255

Retrofit Coal with ACI + DSI + HRI + Scrubber

-- 279

Retrofit Coal with ACI + DSI + HRI + SNCR

-- 129

Retrofit Coal with ACI + DSI + HRI + SNCR + Scrubber

-- 60

Retrofit Coal with ACI + DSI + SCR

-- 393

Retrofit Coal with ACI + DSI + SCR + Scrubber

-- 255

Retrofit Coal with ACI + DSI + Scrubber

-- 279

Retrofit Coal with ACI + DSI + Scrubber + SNCR

-- 60

Retrofit Coal with ACI + DSI + SNCR

-- 148

Retrofit Coal with ACI + HRI

-- 333

Retrofit Coal with ACI + HRI + SCR

-- 436

Retrofit Coal with ACI + HRI + SCR + Scrubber

-- 706

Retrofit Coal with ACI + HRI + Scrubber

-- 583

Retrofit Coal with ACI + HRI + SNCR

-- 130

Retrofit Coal with ACI + HRI + SNCR + Scrubber

-- 270

Retrofit Coal with ACI + SCR

-- 437

Retrofit Coal with ACI + SCR + Scrubber

-- 706

Retrofit Coal with ACI + Scrubber

-- 583

Retrofit Coal with ACI + Scrubber + SNCR

-- 270

Retrofit Coal with ACI + SNCR

-- 141

Retrofit Coal with C2G

-- 599

Retrofit Coal with C2G + SCR

-- 599

Retrofit Coal with CCS

-- 420

Retrofit Coal with CCS + HRI

-- 420

Retrofit Coal with CCS + HRI + SCR

-- 132

Retrofit Coal with CCS + HRI + SCR + Scrubber

-- 154

Retrofit Coal with CCS + HRI + Scrubber

-- 190

Retrofit Coal with CCS + SCR

-- 132

## 86 Retrofits

Plant Type Number of Units Number of IPM Model

Plants

Retrofit Coal with CCS + SCR + Scrubber

-- 154

Retrofit Coal with CCS + Scrubber

-- 190

Retrofit Coal with DSI

-- 192

Retrofit Coal with DSI + HRI

-- 383

Retrofit Coal with DSI + HRI + SCR

-- 513

Retrofit Coal with DSI + HRI + SCR + Scrubber

-- 275

Retrofit Coal with DSI + HRI + Scrubber

-- 244

Retrofit Coal with DSI + HRI + SNCR

-- 110

Retrofit Coal with DSI + SCR

-- 513

Retrofit Coal with DSI + SCR + Scrubber

-- 275

Retrofit Coal with DSI + Scrubber

-- 244

Retrofit Coal with DSI + SNCR

-- 163

Retrofit Coal with HRI

-- 663

Retrofit Coal with HRI + SCR

-- 739

Retrofit Coal with HRI + SCR + Scrubber

-- 1,188

Retrofit Coal with HRI + Scrubber

-- 937

Retrofit Coal with HRI + Scrubber + SNCR

-- 390

Retrofit Coal with HRI + SNCR

-- 183

Retrofit Coal with SCR

-- 370

Retrofit Coal with SCR + Scrubber

-- 1,188

Retrofit Coal with Scrubber

-- 469

Retrofit Coal with Scrubber + SNCR

-- 391

Retrofit Coal with SNCR

-- 92

Retrofit Combined Cycle with CCS

-- 692

Retrofit Oil/Gas steam with SCR

-- 205

Total

-- 22,022

Withdrawn as Uneconomic (Early Retirements)

Plant Type Number of Units Number of IPM Model Plants

CC Withdrawn as Uneconomic

-- 823

Coal Withdrawn as Uneconomic

-- 4,756

CT Withdrawn as Uneconomic

-- 2,258

IGCC Withdrawn as Uneconomic

-- 5

Non

- Fossil Withdrawn as Uneconomic

-- 823

Nuke Withdrawn as Uneconomic

-- 104

O/G Withdrawn as Uneconomic

-- 1,134

Total

-- 9,903

Grand Total (Existing and Planned/Committed + New + Retrofits + Early Retirements): 43204

Notes:

1 

## Non Fossil Other includes units whose fuel is municipal solid waste, tires, and other non

- fossil waste.

## 87 Table 4

‐ 11 Summary of Planned

- Committed Units in NEEDS v.5.1 5 for EPA Base Case v.5.1 5

Type Capacity (MW) Year Range Described

Renewables/Non

- conventional

Biomass 1,101 2013

- 20 15

Fuel Cell 77 2013

- 20 15

Geothermal 230 2013

- 20 16

Hydro 1,646 2013

- 20 16

Import 200 201 5

- 20 15

Landfill Gas 427 2013

- 20 15

Municipal Solid Waste 203 201 5

- 20 15

Non

- Fossil Waste 306 2013

- 20 15

Pumped Storage

- -

Solar PV 9,769 2013

- 20 18

Solar Thermal 1,652 2013

- 20 16

Tires 96 201 5

- 20 15

Wind 17,365 2013

- 2020

Subtotal 33,070

Fossil/Conventional

Coal Steam 2 2013

- 20 15

Combined Cycle 23,394 2013

- 20 15

Combustion Turbine 5,896 2013

- 20 15

Fossil Waste 17 2013

- 20 15

IGCC 522 2013

– 20 15

Nuclear 5,522 2015

– 20 20

O/G Steam 289 2013

- 20 15

Subtotal 35,641

Grand Total 68,711

Table 4

‐ 12 Planned

- Committed Units by Model Region in NEEDS v.5.1 5 for EPA Base Case v.5.1 5



# IPM Region Plant Type Capacity (MW)

ERC_REST Biomass 50

Combined Cycle 2999

Combustion Turbine 325

Hydro 2

Landfill Gas 6

Non

- Fossil Waste 33

Solar PV 189

Wind 833

ERC_WEST Solar PV 62

Wind 1890

FRCC Biomass 158

Combined Cycle 4131

Combustion Turbine 6

## 88 

# IPM Region Plant Type Capacity (MW)

Landfill Gas 10

Municipal Solid Waste 85

Solar PV 20

MAP_WAUE Combustion Turbine 60

Wind 50

MIS_IA Combined Cycle 646

Combustion Turbine 5

Wind 1216

MIS_IL Biomass 15

Wind 98

MIS_INKY Hydro 162

Landfill Gas 3

Solar PV 92

Wind 20

MIS_LMI Combustion Turbine 96

Landfill Gas 4

Non

- Fossil Waste 4

O/G steam 13

Solar PV 1

Wind 765

MIS_MAPP Combustion Turbine 328

Non

- Fossil Waste 6

Wind 581

MIS_MIDA Biomass 3

Combustion Turbine 8

Hydro 55

Landfill Gas 5

Wind 1101

MIS_MNWI Combustion Turbine 12

Hydro 11

Non

- Fossil Waste 13

Solar PV 3

Wind 249

MIS_MO Combustion Turbine 27

Landfill Gas 17

Solar PV 5

MIS_WUMS Biomass 117

Combustion Turbine 2

Hydro 8

Landfill Gas 8

Municipal Solid Waste 1

Non

- Fossil Waste 3

Wind 10

## 89 

# IPM Region Plant Type Capacity (MW)

NENG_CT Biomass 81

Combustion Turbine 23

Fuel Cell 17

Solar PV 10

NENG_ME Biomass 26

Hydro 1

Wind 216

NENGREST Biomass 69

Combustion Turbine 40

Hydro 2

Landfill Gas 40

Non

- Fossil Waste 1

Solar PV 202

Wind 81

NY_Z_A&B Biomass 15

Hydro 4

Solar PV 1

Wind 94

NY_Z_C&E Combustion Turbine 2

Landfill Gas 12

Wind 32

NY_Z_F Hydro 4

Solar PV 2

NY_Z_G

- I Hydro 0.8

Non

- Fossil Waste 19

Solar PV 2

NY_Z_J Combustion Turbine 4

Fuel Cell 5

Solar PV 2

NY_Z_K Combustion Turbine 0.2

Solar PV 11

PJM_AP Combined Cycle 1280

Hydro 44

Landfill Gas 9

Solar PV 40

Wind 118

PJM_ATSI Combustion Turbine 14

Landfill Gas 13

Non

- Fossil Waste 140

Solar PV 8

Wind 3

PJM_COMD Combined Cycle 882

O/G steam 259

## 90 

# IPM Region Plant Type Capacity (MW)

Solar PV 20

Wind 304

PJM_Dom Biomass 94

Combined Cycle 2158

Combustion Turbine 65

Landfill Gas 33

Solar PV 72

PJM_EMAC Biomass 38

Combined Cycle 2485

Combustion Turbine 207

Fuel Cell 21

Hydro 126

Landfill Gas 7

Non

- Fossil Waste 7

Solar PV 293

Wind 2

PJM_PENE Biomass 1

Combined Cycle 765

Combustion Turbine 2

Hydro 7

Landfill Gas 7

O/G steam 4

Tires 96

PJM_SMAC Combined Cycle 726

Combustion Turbine 20

Landfill Gas 5

Non

- Fossil Waste 24

O/G steam 9

Solar PV 6

PJM_West Biomass 5

Combined Cycle 539

Landfill Gas 12

Non

- Fossil Waste 7

Solar PV 10

Wind 260

PJM_WMAC Biomass 4

Combined Cycle 765

Combustion Turbine 10

Landfill Gas 3

Non

- Fossil Waste 20

Solar PV 1

S_C_KY Combined Cycle 640

Hydro 105

Landfill Gas 2

## 91 

# IPM Region Plant Type Capacity (MW)

S_C_TVA Biomass 13

Hydro 28

IGCC 522

Landfill Gas 3

Nuclear 1122

Solar PV 95

S_D_AMSO Biomass 5

Combined Cycle 561

Municipal Solid Waste 115

O/G steam 4

S_D_WOTA Biomass 96

Hydro 24

S_SOU Biomass 122

Hydro 2

Landfill Gas 15

Non

- Fossil Waste 2

Nuclear 2200

Solar PV 37

S_VACA Biomass 3

Combined Cycle 622

Combustion Turbine 92

Fuel Cell 5

Hydro 30

Landfill Gas 60

Non

- Fossil Waste 12

Nuclear 2200

Solar PV 447

SPP_N Biomass 6

Combined Cycle 100

Combustion Turbine 113

Landfill Gas 4

Municipal Solid Waste 2

Solar PV 8

Wind 1500

SPP_NEBR Landfill Gas 5

Wind 435

SPP_SE Combined Cycle 79

SPP_SPS Combustion Turbine 521

Non

- Fossil Waste 3

Solar PV 59

Wind 3388

SPP_WEST Coal Steam 2

Combustion Turbine 122

## 92 

# IPM Region Plant Type Capacity (MW)

Hydro 80

Landfill Gas 3

Wind 604

WEC_CALN Combustion Turbine 794

Landfill Gas 17

Non

- Fossil Waste 2

Solar PV 1138

Solar Thermal 30

WEC_LADW Combined Cycle 828

Combustion Turbine 1266

Fuel Cell 5

Landfill Gas 20

Solar PV 559

WEC_SDGE Biomass 2

Combustion Turbine 35

Fuel Cell 6

Import 200

Landfill Gas 8

Solar PV 64

WECC_AZ Landfill Gas 3

Non

- Fossil Waste 0.2

Solar PV 896

Solar Thermal 260

Wind 81

WECC_CO Biomass 111

Combined Cycle 588

Combustion Turbine 90

Hydro 24

Landfill Gas 8

Solar PV 15

Solar Thermal 1

Wind 536

WECC_ID Hydro 1

Solar PV 20

Wind 220

WECC_IID Geothermal 25

Solar PV 1189

WECC_MT Biomass 4

Hydro 63

Landfill Gas 2

Wind 21

WECC_NM Combustion Turbine 312

Fossil Waste 17

Geothermal 12

## 93 

# IPM Region Plant Type Capacity (MW)

Solar PV 92

Wind 567

WECC_NNV Combustion Turbine 1

Geothermal 119

Hydro 0.2

Solar PV 3

Solar Thermal 112

WECC_PNW Biomass 64

Combined Cycle 500

Combustion Turbine 245

Geothermal 11

Hydro 864

Landfill Gas 65

Non

- Fossil Waste 11

Solar PV 6

Wind 998

WECC_SCE Combustion Turbine 852

Fuel Cell 9

Landfill Gas 3

Solar PV 3121

Solar Thermal 1247

Wind 1008

WECC_SF Combined Cycle 741

Combustion Turbine 72

Fuel Cell 9

Landfill Gas 6

Solar PV 44

Wind 2

WECC_SNV Landfill Gas 11

Solar PV 923

WECC_UT Combined Cycle 1258

Combustion Turbine 8

Geothermal 63

Hydro 1

Solar Thermal 2

Wind 82

WECC_WY Combined Cycle 100

Combustion Turbine 120

Wind 2

## 94 Table 4

‐ 33 Nuclear Uprating (MW) as Incorporated in EPA Base Case v.5.1 5 from AEO 201 5

Name Plant ID Unit ID Year Change in MWs

Fort Calhoun 2289 1 2017 75

Table 4

- 34 Characteristics of Existing Nuclear Units

Region State Plant Name On

- Line

Year Capacity

(MW) Heat Rate

(Btu/kWh) FOM VOM

Needs

Unique ID (2011$

/kW

- yr) (2011

mills/kWh)

ERC_REST Texas Comanche Peak 6145_G_1 1990 1205 10,460 182 0.18

Coman che Peak 6145_G_2 1993 1195 10,460 182 0.18

South Texas Project 6251_G_1 1988 1280 10,460 199 0.18

South Texas Project 6251_G_2 1989 1280 10,460 199 0.18

FRCC Florida St Lucie 6045_G_1 1976 981 10,460 161 0.15

St Lucie 6045_G_2 1983 981 10,460 161 0.16

Turkey Point 621_G_3 1972 802 10,460 227 0.21

Turkey Point 621_G_4 1973 802 10,460 227 0.22

MIS_IA Iowa Duane Arnold

Energy Center 1060_G_1 1975 601 10,460 188 0.18

MIS_IL Illinois Clinton Power

Station 204_G_1 1987 1065 10,460 199 0.18

MIS_LMI Michigan Fermi 1729_G_2 1988 1085 10,460 179 0.17

Palisades 1715_G_1 1972 782 10,460 200 0.18

MIS_MNWI Minnesota Monticello 1922_G_1 1971 633 10,270 252 0.26

Prairie Island 1925_G_1 1974 521 11,440 236 0.24

Prairie Island 1925_G_2 1974 519 11,440 236 0.23

MIS_MO Missouri Callaway 6153_G_1 1984 1190 10,460 124 0.12

MIS_WUMS Wisconsin Point Beach Nuclear

Plant 4046_G_1 1970 591 10,460 204 0.18

Point Beach Nuclear

Plant 4046_G_2 1972 591 10,460 204 0.18

NENG_CT Connecticut Millstone 566_G_2 1975 869 10,460 194 0.19

Millstone 566_G_3 1986 1233 10,460 180 0.19

NENGREST Massachuset

ts Pilgrim Nuclear

Power Station 1590_G_1 1972 677 10,460 226 0.18

N ew

Hampshire Seabrook 6115_G_1 1990 1246 10,460 199 0.20

NY_Z_A&B New York R E Ginna Nuclear

Power Plant 6122_G_1 1970 490 10,460 217 0.18

NY_Z_C &E New York James A Fitzpatrick 6110_G_1 1976 716 10,460 216 0.18

## 95 Region State Plant Name On

- Line

Year Capacity

(MW) Heat Rate

(Btu/kWh) FOM VOM

Needs

Unique ID (2011$

/kW

- yr) (2011

mills/kWh)

Nine Mile Point

Nuclear Station 2589_G_1 1969 531 10,460 204 0.18

Nine Mile Point

Nuclear Station 2589_G_2 1987 965 10,460 199 0.18

NY_Z_G

- I New York Indian Point 2 2497_G_2 1973 1020 10,460 207 0.18

Indian Point 3 8907_G_3 1976 1041 10,460 195 0.18

PJM_ATSI Ohio Davis Besse 6149_G_1 1977 894 10,460 180 0.20

Perry 6020_G_1 1987 1272 10,460 187 0.65

PJM_COMD Illinois Braidwood

Generation Station 6022_G_1 1988 1178 10,460 194 0.17

Braidwood

Generation Station 6022_G_2 1988 1152 10,460 194 0.18

Byron Generating

Station 6023_G_1 1985 1164 10,460 194 0.18

Byron Generating

Station 6023_G_2 1987 1136 10,460 194 0.17

Dresden Generating

Station 869_G_2 1970 883 10,460 212 0.17

Dresden Generating

Station 869_G_3 1971 867 10,460 212 0.18

LaSalle Generating

Station 6026_G_1 1984 1137 10,427 193 0.17

LaSalle Generating

Station 6026_G_2 1984 1140 10,427 193 0.17

Quad Cities

Generating Station 880_G_1 1972 908 10,460 193 0.17

Quad Cities

Generating Station 880_G_2 1972 911 10,460 193 0.17

PJM_Dom Virginia North Anna 6168_G_1 1978 943 10,460 114 0.11

North Anna 6168_G_2 1980 943 10,460 114 0.11

Surry 3806_G_1 1972 872 10,427 146 0.13

Surry 3806_G_2 1973 872 10,427 149 0.13

PJM_EMAC New Jersey Oyster Creek 2388_G_1 1969 615 10,460 225 0.18

PSEG Hope Creek

Generating Station 6118_G_1 1986 1174 10,460 180 0.17

PSEG Salem

Generating Station 2410_G_1 1977 1168 10,460 199 0.18

PSEG Salem

Generating Station 2410_G_2 1981 1158 10,460 199 0.18

Pennsylvania Limerick 6105_G_1 1986 1146 10,460 200 0.18

Limerick 6105_G_2 1990 1150 10,460 200 0.18

Peach Bottom 3166_G_2 1974 1125 10,460 199 0.17

Peach Bottom 3166_G_3 1974 1125 10,460 199 0.18

PJM_SMAC Maryland Calvert Cliffs Nuclear

Power Plant 6011_G_1 1975 866 10,460 199 0.17

Calvert Cliffs Nuclear

Power Plant 6011_G_2 1977 850 10,460 199 0.17

## 96 Region State Plant Name On

- Line

Year Capacity

(MW) Heat Rate

(Btu/kWh) FOM VOM

Needs

Unique ID (2011$

/kW

- yr) (2011

mills/kWh)

PJM_West Michigan Donald C Cook 6000_G_1 1975 1009 10,460 151 0.21

Donald C Cook 6000_G_2 1978 1060 10,460 151 0.13

Pennsylvania Beaver Valley 6040_G_1 1976 921 10,460 230 0.55

Beaver Valley 6040_G_2 1987 914 10,460 230 0.58

PJM_WMAC Pennsylvania PPL Susquehanna 6103_G_1 1983 1260 10,460 186 0.20

PPL Susquehanna 6103_G_2 1985 1260 10,460 186 0.18

Three Mile Island 8011_G_1 1974 805 10,460 194 0.18

S_C_TVA Alabama Browns Ferry 46_G_1 1974 1101 10,460 199 0.19

Browns Ferry 46_G_2 1975 1104 10,460 199 0.19

Browns Ferry 46_G_3 1977 1105 10,460 199 0.20

Tennessee Sequoyah 6152_G_1 1981 1152 10,460 210 0.18

Sequoyah 6152_G_2 1982 1126 10,460 210 0.18

Watts Bar Nuclear

Plant 7722_G_1 1996 1123 10,460 198 0.19

Watts Bar Nuclear

Plant 7722_G_2 2015 1122 10,460 137 2.16

S_D_AMSO Louisiana Waterford 3 4270_G_3 1985 1159 10,460 181 0.13

S_D_N_AR Arkansas Arkansas Nuclear

One 8055_G_1 1974 836 10,460 162 0.13

Arkansas Nuclear

One 8055_G_2 1980 992 10,460 162 0.13

S_D_REST Louisiana River Bend 6462_G_1 1986 975 10,460 163 0.17

Mississippi Grand Gulf 6072_G_1 1985 1419 10,460 165 0.13

S_SOU Alabama Joseph M Farley 6001_G_1 1977 874 10,460 149 0.14

Joseph M Farley 6001_G_2 1981 860 10,460 149 0.14

Georgia Edwin I Hatch 6051_G_1 1975 876 10,460 133 0.13

Edwin I Hatch 6051_G_2 1979 883 10,460 133 0.14

Vogtle 649_G_1 1987 1150 10,460 111 0.09

Vogtle 649_G_2 1989 1152 10,460 111 0.09

Vogtle 649_G_3 2017 1100 10,400 113 2.16

Vogtle 649_G_4 2018 1100 10,400 113 2.16

S_VACA North

Carolina Brunswick 6014_G_1 1977 938 10,460 155 0.14

Brunswick 6014_G_2 1975 932 10,460 155 0.15

Harris 6015_G_1 1987 928 10,460 187 0.16

## 97 Region State Plant Name On

- Line

Year Capacity

(MW) Heat Rate

(Btu/kWh) FOM VOM

Needs

Unique ID (2011$

/kW

- yr) (2011

mills/kWh)

McGuire 6038_G_1 1981 1158 10,460 137 0.11

McGuire 6038_G_2 1984 1158 10,460 137 0.11

South

Carolina Catawba 6036_G_1 1985 1129 10,460 138 0.13

Catawba 6036_G_2 1986 1129 10,460 138 0.12

H B Robinson 3251_G_2 1971 741 10,460 142 0.15

Oconee 3265_G_1 1973 846 10,460 137 0.13

Oconee 3265_G_2 1974 846 10,460 137 0.12

Oconee 3265_G_3 1974 846 10,460 137 0.12

V C Summer 6127_G_1 1984 971 10,460 171 0.17

V C Summer 6127_G_2 2017 1100 10,400 113 2.16

V C Summer 6127_G_3 2018 1100 10,400 113 2.16

SPP_N Kansas Wolf Creek

Generating Station 210_G_1 1985 1175 10,460 158 0.17

SPP_NEBR Nebraska Cooper 8036_G_1 1974 766 10,460 199 0.18

Fort Calhoun 2289_G_1 1973 479 10,460 187 0.22

WEC_CALN California Diablo Canyon 6099_G_1 1985 1122 10,460 170 0.17

Diablo Canyon 6099_G_2 1986 1118 10,460 170 0.18

WECC_AZ Arizona Palo Verde 6008_G_1 1986 1311 10,460 236 0.23

Palo Verde 6008_G_2 1986 1314 10,460 236 0.23

Palo Verde 6008_G_3 1988 1312 10,460 236 0.22

WECC_PNW Washington Columbia Generating

Station 371_G_2 1984 1132 10,460 202 0.21

## 98 Table 4

- 35 Capacity Not Included Based on EIA form 860

– Existing Units

Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Hospira Inc 55788 GEN1 Combustion Turbine New York 1.1 Dropped

- Onsite Unit

Hospira Inc 55788 GEN2 Combustion Turbine New York 1.1 Dropped

- Onsite Unit

AG Processing Inc 10223 E.C. Coal Steam Iowa 8.5 Dropped

- Onsite Unit

Oxford Cogeneration Facility 52093 GEN1 Combustion Turbine California 2.4 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Oxford Cogeneration Facility 52093 GEN2 Combustion Turbine California 2.4 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

South Belridge Cogeneration Facility 50752 GEN1 Combustion Turbine California 19 Dropped

- Onsite Unit

South Belridge Cogeneration Facility 50752 GEN2 Combustion Turbine California 19 Dropped

- Onsite Unit

South Belridge Cogeneration Facility 50752 GEN3 Combustion Turbine California 19 Dropped

- Onsite Unit

Lost Hills Cogeneration Plant 52077 GEN4 Combustion Turbine California 2.7 Dropped

- Onsite Unit

Lost Hills Cogeneration Plant 52077 GEN5 Combustion Turbine California 2.7 Dropped

- Onsite Unit

Lost Hills Cogeneration Plant 52077 GEN6 Combustion Turbine California 2.7 Dropped

- Onsite Unit

AES Hawaii 10673 GEN1 Coal Steam Hawaii 180 Dropped

- in Alaska or in Hawaii

Agrium Kenai Nitrogen Operations 54452 744A Combustion Turbine Alaska 2.5 Dropped

- Onsite Unit

Agrium Kenai Nitrogen Operations 54452 744B Combustion Turbine Alaska 2.5 Dropped

- Onsite Unit

Agrium Kenai Nitrogen Operations 54452 744C Combustion Turbine Alaska 2.5 Dropped

- Onsite Unit

Agrium Kenai Nitrogen Operations 54452 744D Combustion Turbine Alaska 2.5 Dropped

- Onsite Unit

Agrium Kenai Nitrogen Operations 54452 744E Combustion Turbine Alaska 2.5 Dropped

- Onsite Unit

Southside Water Reclamation Plant 10339 GEN1 Non

- Fossil Waste New Mexico 2.1 Dropped

- Onsite Unit

Southside Water Reclamation Plant 10339 GEN2 Non

- Fossil Waste New Mexico 2.1 Dropped

- Onsite Unit

Southside Water Reclamation Plant 10339 GEN3 Non

- Fossil Waste New Mexico 1.1 Dropped

- Onsite Unit

Southside Water Reclamation Plant 10339 GEN4 Non

- Fossil Waste New Mexico 1.1 Dropped

- Onsite Unit

Annex Creek 62 5 Hydro Alaska 1.8 Dropped

- in Alaska or in Hawaii

Annex Creek 62 6 Hydro Alaska 1.8 Dropped

- in Alaska or in Hawaii

Gold Creek 63 1 Hydro Alaska 0.8 Dropped

- in Alaska or in Hawaii

Gold Creek 63 2 Hydro Alaska 0.4 Dropped

- in Alaska or in Hawaii

Gold Creek 63 3 Hydro Alaska 0.4 Dropped

- in Alaska or in Hawaii

Gold Creek 63 IC1 Combustion Turbine Alaska 1.2 Dropped

- in Alaska or in Hawaii

Gold Creek 63 IC2 Combustion Turbine Alaska 1.2 Dropped

- in Alaska or in Hawaii

Gold Creek 63 IC3 Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

## 99 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Gold Creek 63 IC4 Combustion Turbine Alaska 3.5 Dropped

- in Alaska or in Hawaii

Gold Creek 63 IC5 Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Lemon Creek 64 1 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Lemon Creek 64 2 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Lemon Creek 64 3 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Lemon Creek 64 5 Combustion Turbine Alaska 17.5 Dropped

- in Alaska or in Hawaii

Lemon Creek 64 6 Combustion Turbine Alaska 17.5 Dropped

- in Alaska or in Hawaii

Lemon Creek 64 7 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Lemon Creek 64 IC10 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Lemon Creek 64 IC11 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Lemon Creek 64 IC12 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Lemon Creek 64 IC8 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Lemon Creek 64 IC9 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Salmon Creek 1 65 HY7 Hydro Alaska 5.2 Dropped

- in Alaska or in Hawaii

Snettisham 78 1 Hydro Alaska 23.5 Dropped

- in Alaska or in Hawaii

Snettisham 78 2 Hydro Alaska 23.5 Dropped

- in Alaska or in Hawaii

Snettisham 78 3 Hydro Alaska 31 Dropped

- in Alaska or in Hawaii

Auke Bay 7250 13 Combustion Turbine Alaska 2.8 Dropped

- in Alaska or in Hawaii

Auke Bay 7250 14 Combustion Turbine Alaska 23 Dropped

- in Alaska or in Hawaii

Auke Bay 7250 4 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Lake Dorothy Hydroelectric Project 57085 1 Hydro Alaska 14.3 Dropped

- in Alaska or in Hawaii

Skagway 66 1 Hydro Alaska 0.4 Dropped

- in Alaska or in Hawaii

Skagway 66 2 Hydro Alaska 0.1 Dropped

- in Alaska or in Hawaii

Skagway 66 3 Hydro Alaska 0.3 Dropped

- in Alaska or in Hawaii

Skagway 66 4 Hydro Alaska 0.2 Dropped

- in Alaska or in Hawaii

Skagway 66 6A Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

Skagway 66 7A Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Skagway 66 8A Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Skagway 66 9 Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Haines 69 10 Combustion Turbine Alaska 1.2 Dropped

- in Alaska or in Hawaii

## 100 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Haines 69 5 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

Haines 69 7A Combustion Turbine Alaska 2.8 Dropped

- in Alaska or in Hawaii

Haines 69 IC8A Combustion Turbine Alaska 1.6 Dropped

- in Alaska or in Hawaii

Tok 406 3A Combustion Turbine Alaska 1.3 Dropped

- in Alaska or in Hawaii

Tok 406 4A Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Tok 406 5A Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Tok 406 6 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Tok 406 7a Combustion Turbine Alaska 2.3 Dropped

- in Alaska or in Hawaii

Tok 406 8 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Tok 406 9 Combustion Turbine Alaska 0.9 Dropped

- in Alaska or in Hawaii

Craig 421 1 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

Craig 421 3A Combustion Turbine Alaska 1.6 Dropped

- in Alaska or in Hawaii

Craig 421 5 Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Craig 421 6 Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Hydaburg 423 1A Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Hydaburg 423 3A Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Hydaburg 423 5 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Northway 7169 1A Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Northway 7169 2A Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Northway 7169 5 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Thorne Bay Plant 7414 2 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

Thorne Bay Plant 7414 4 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Goat Lake Hydro 7751 1 Hydro Alaska 4 Dropped

- in Alaska or in Hawaii

Black Bear Lake 7752 1 Hydro Alaska 4.5 Dropped

- in Alaska or in Hawaii

False Island 56146 1 Combustion Turbine Alaska 1.3 Dropped

- in Alaska or in Hawaii

Viking 56147 1 Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

South Fork 56265 1 Hydro Alaska 1.9 Dropped

- in Alaska or in Hawaii

Kasidaya Creek Hydro 56542 1 Hydro Alaska 3 Dropped

- in Alaska or in Hawaii

Emmonak 6314 2 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Emmonak 6314 4a Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

## 101 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Emmonak 6314 5a Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Emmonak 6314 6 Combustion Turbine Alaska 0.9 Dropped

- in Alaska or in Hawaii

Hooper Bay 6319 3A Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Hooper Bay 6319 4A Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Hooper Bay 6319 5 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Hooper Bay 6319 6 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Kiana 6323 1B Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Kiana 6323 3A Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Kiana 6323 4 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Mountain Village 6329 1 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Mountain Village 6329 3A Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Mountain Village 6329 4 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

Mountain Village 6329 5 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Noorvik 6330 1A Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Noorvik 6330 2A Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Noorvik 6330 3 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

St Marys 6338 1B Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

St Marys 6338 2 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

St Marys 6338 3 Combustion Turbine Alaska 0.9 Dropped

- in Alaska or in Hawaii

Selawik 6341 1A Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Selawik 6341 2A Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Selawik 6341 3A Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

Shishmaref 6345 1 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Shishmaref 6345 2 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Shishmaref 6345 3 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Shishmaref 6345 4 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Togiak 6348 2a Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Togiak 6348 4 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Togiak 6348 4a Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Noatak 57051 UNIT2 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

## 102 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Noatak 57051 UNIT4 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Noatak 57051 UNIT5 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Savoonga 57052 UNIT1 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Savoonga 57052 UNIT2 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Savoonga 57052 UNIT3 Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

Alakanuk 57053 UNIT1 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Alakanuk 57053 UNIT2 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Alakanuk 57053 UNIT3 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Upper Kalskag 57054 UNIT1 Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Upper Kalskag 57054 UNIT2 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Upper Kalskag 57054 UNIT3 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Stebbins 57055 UNIT1 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Stebbins 57055 UNIT2 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Stebbins 57055 UNIT3 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Scammon Bay 57056 UNIT1 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Scammon Bay 57056 UNIT2 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Scammon Bay 57056 UNIT3 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Quinhagak 57057 UNIT1 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Quinhagak 57057 UNIT2 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Quinhagak 57057 UNIT3 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Pilot Station 57058 UNIT1 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Pilot Station 57058 UNIT2 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Pilot Station 57058 UNIT3 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Koyuk 57059 UNIT1 Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Koyuk 57059 UNIT2 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Koyuk 57059 UNIT3 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Elim 57060 UNIT1 Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Elim 57060 UNIT2 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Elim 57060 UNIT3 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

St. Michael 57061 UNIT1 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

## 103 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

St. Michael 57061 UNIT2 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

St. Michael 57061 UNIT3 Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Gambell 57062 UNIT1 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Gambell 57062 UNIT2 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Gambell 57062 UNIT3 Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

Shungnak 57063 UNIT1 Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Shungnak 57063 UNIT2 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Shungnak 57063 UNIT3 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Shungnak 57063 UNIT4 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Kotlik 57064 UNIT1 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Kotlik 57064 UNIT2 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Kotlik 57064 UNIT3 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Kotlik 57064 UNIT4 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Kivalina 57065 UNIT1 Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Kivalina 57065 UNIT2 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Kivalina 57065 UNIT3 Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Kivalina 57065 UNIT4 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Kasigluk 57066 5A Combustion Turbine Alaska 0.7 Dropped

- in Alaska or in Hawaii

Kasigluk 57066 UNIT1 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Kasigluk 57066 UNIT2 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Toksook Bay 57067 UNIT1 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Toksook Bay 57067 UNIT2 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Toksook Bay 57067 UNIT3 Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

Akron Recycle Energy Plant 54265 1 Biomass Ohio 2 Dropped

- Onsite Unit

Akron Recycle Energy Plant 54265 2 Biomass Ohio 2 Dropped

- Onsite Unit

Cheoah 54899 1 Hydro North Carolina 21 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Cheoah 54899 2 Hydro North Carolina 21 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Cheoah 54899 3 Hydro North Carolina 21 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Cheoah 54899 4 Hydro North Carolina 21 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Alliant SBD 9402 Climax 54930 5100 Combustion Turbine Iowa 1.6 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

## 104 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Alliant SBD 9402 Climax 54930 5200 Combustion Turbine Iowa 1.6 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Alliant SBD 9402 Climax 54930 5300 Combustion Turbine Iowa 1.6 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Alliant SBD 9402 Climax 54930 5400 Combustion Turbine Iowa 1.6 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Alliant SBD 9402 Climax 54930 5500 Combustion Turbine Iowa 1.6 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Big Spring Texas Refinery 10569 GENA Non

- Fossil Waste Texas 1.5 Dropped

- Onsite Unit

Wasson CO2 Removal Plant 52122 GEN1 Combustion Turbine Texas 14 Dropped

- Onsite Unit

Amalgamated Sugar Twin Falls 10504 1500 Coal Steam Idaho 1.2 Dropped

- Onsite Unit

Amalgamated Sugar Twin Falls 10504 2500 Coal Steam Idaho 2.3 Dropped

- Onsite Unit

Amalgamated Sugar Twin Falls 10504 4000 Coal Steam Idaho 5 Dropped

- Onsite Unit

American Crystal Sugar Hillsboro 54210 G1 Coal Steam North Dakota 13.3 Dropped

- Onsite Unit

American Crystal Sugar Moorhead 54211 G1 Coal Steam Minnesota 3 Dropped

- Onsite Unit

American Crystal Sugar Moorhead 54211 G2 Coal Steam Minnesota 2 Dropped

- Onsite Unit

American Crystal Sugar Crookston 54212 G1 Coal Steam Minnesota 3.5 Dropped

- Onsite Unit

American Crystal Sugar Crookston 54212 G2 Coal Steam Minnesota 3 Dropped

- Onsite Unit

American Crystal Sugar Drayton 54213 G1 Coal Steam North Dakota 6 Dropped

- Onsite Unit

American Crystal Sugar East Grand Forks 54214 G1 Coal Steam Minnesota 2.5 Dropped

- Onsite Unit

American Crystal Sugar East Grand Forks 54214 G2 Coal Steam Minnesota 5 Dropped

- Onsite Unit

Domino Sugar Arabi Plant 54512 TG1 O/G Steam Louisiana 4.2 Dropped

- Onsite Unit

Domino Sugar Arabi Plant 54512 TG2 O/G Steam Louisiana 2.4 Dropped

- Onsite Unit

Domino Sugar Arabi Plant 54512 TG3 O/G Steam Louisiana 3 Dropped

- Onsite Unit

Anchorage 1 75 1 Combustion Turbine Alaska 14 Dropped

- in Alaska or in Hawaii

Anchorage 1 75 2 Combustion Turbine Alaska 14 Dropped

- in Alaska or in Hawaii

Anchorage 1 75 3R Combustion Turbine Alaska 29.3 Dropped

- in Alaska or in Hawaii

Anchorage 1 75 4 Combustion Turbine Alaska 31.1 Dropped

- in Alaska or in Hawaii

Eklutna Hydro Project 77 1 Hydro Alaska 22.2 Dropped

- in Alaska or in Hawaii

Eklutna Hydro Project 77 2 Hydro Alaska 22.2 Dropped

- in Alaska or in Hawaii

George M Sullivan Generation Plant 2 6559 5 Combined Cycle Alaska 33.8 Dropped

- in Alaska or in Hawaii

George M Sullivan Generation Plant 2 6559 6 Combined Cycle Alaska 34 Dropped

- in Alaska or in Hawaii

George M Sullivan Generation Plant 2 6559 7 Combined Cycle Alaska 74.4 Dropped

- in Alaska or in Hawaii

George M Sullivan Generation Plant 2 6559 GT8 Combustion Turbine Alaska 77.7 Dropped

- in Alaska or in Hawaii

## 105 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Anheuser

- Busch St Louis 10430 GEN1 Coal Steam Missouri 11 Dropped

- Onsite Unit

Anheuser

- Busch St Louis 10430 GEN3 Coal Steam Missouri 11 Dropped

- Onsite Unit

Anheuser

- Busch St Louis 10430 GEN4 Coal Steam Missouri 4.1 Dropped

- Onsite Unit

Anheuser

- Busch Jacksonville 10431 GEN1 Combustion Turbine Florida 8.6 Dropped

- Onsite Unit

Archer Daniels Midland Clinton 10860 1A Coal Steam Iowa 75 Dropped

- Onsite Unit

Archer Daniels Midland Clinton 10860 2A Coal Steam Iowa 105 Dropped

- Onsite Unit

Archer Daniels Midland Des Moines 10861 GEN1 Coal Steam Iowa 7.9 Dropped

- Onsite Unit

Archer Daniels Midland Lincoln 10862 GEN1 Coal Steam Nebraska 7.9 Dropped

- Onsite Unit

Archer Daniels Midland Mankato 10863 GEN1 Coal Steam Minnesota 6.2 Dropped

- Onsite Unit

Archer Daniels Midland Cedar Rapids 10864 GEN1 Coal Steam Iowa 31 Dropped

- Onsite Unit

Archer Daniels Midland Cedar Rapids 10864 GEN2 Coal Steam Iowa 31 Dropped

- Onsite Unit

Archer Daniels Midland Cedar Rapids 10864 GEN3 Coal Steam Iowa 31 Dropped

- Onsite Unit

Archer Daniels Midland Cedar Rapids 10864 GEN4 Coal Steam Iowa 31 Dropped

- Onsite Unit

Archer Daniels Midland Cedar Rapids 10864 GEN5 Coal Steam Iowa 31 Dropped

- Onsite Unit

Archer Daniels Midland Cedar Rapids 10864 GEN6 Coal Steam Iowa 105 Dropped

- Onsite Unit

Archer Daniels Midland Decatur 10865 GEN2 Coal Steam Illinois 31 Dropped

- Onsite Unit

Archer Daniels Midland Decatur 10865 GEN3 Coal Steam Illinois 31 Dropped

- Onsite Unit

Archer Daniels Midland Decatur 10865 GEN4 Coal Steam Illinois 31 Dropped

- Onsite Unit

Archer Daniels Midland Decatur 10865 GEN5 Coal Steam Illinois 31 Dropped

- Onsite Unit

Archer Daniels Midland Decatur 10865 GEN6 Coal Steam Illinois 31 Dropped

- Onsite Unit

Archer Daniels Midland Decatur 10865 GEN7 Coal Steam Illinois 75 Dropped

- Onsite Unit

Archer Daniels Midland Decatur 10865 GEN8 Coal Steam Illinois 105 Dropped

- Onsite Unit

Archer Daniels Midland Peoria 10866 GEN1 Coal Steam Illinois 1.5 Dropped

- Onsite Unit

Archer Daniels Midland Peoria 10866 GEN2 Coal Steam Illinois 1.5 Dropped

- Onsite Unit

Archer Daniels Midland Peoria 10866 GEN3 Coal Steam Illinois 4 Dropped

- Onsite Unit

Archer Daniels Midland Peoria 10866 GEN4 Coal Steam Illinois 4 Dropped

- Onsite Unit

Archer Daniels Midland Peoria 10866 GEN5 Coal Steam Illinois 4 Dropped

- Onsite Unit

Archer Daniels Midland Peoria 10866 GEN6 Combustion Turbine Illinois 15 Dropped

- Onsite Unit

Archer Daniels Midland Peoria 10866 GEN7 Combustion Turbine Illinois 15 Dropped

- Onsite Unit

Archer Daniels Midland Peoria 10866 GEN8 Combustion Turbine Illinois 10 Dropped

- Onsite Unit

## 106 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Galesburg 54310 GEN1 Combustion Turbine Illinois 1 Dropped

- Onsite Unit

Galesburg 54310 GEN2 Combustion Turbine Illinois 1 Dropped

- Onsite Unit

Galesburg 54310 GEN3 Combustion Turbine Illinois 1 Dropped

- Onsite Unit

Archer Daniels Midland Southport 54316 GEN1 Combustion Turbine North Carolina 15 Dropped

- Onsite Unit

Archer Daniels Midland Southport 54316 GEN2 Combustion Turbine North Carolina 15 Dropped

- Onsite Unit

Archer Daniels Midland Southport 54316 GEN3 Combustion Turbine North Carolina 15 Dropped

- Onsite Unit

Enderlin 54908 GEN1 Biomass North Dakota 5.1 Dropped

- Onsite Unit

Enderlin 54908 GEN2 Biomass North Dakota 4.7 Dropped

- Onsite Unit

Mansfield 55046 GEN1 Combustion Turbine Massachusetts 1 Dropped

- Onsite Unit

Mansfield 55046 GEN2 Combustion Turbine Massachusetts 1 Dropped

- Onsite Unit

Mansfield 55046 GEN3 Combustion Turbine Massachusetts 1 Dropped

- Onsite Unit

Walhalla 55638 GEN1 Coal Steam North Dakota 2 Dropped

- Onsite Unit

Perma Treat Corporation 10053 1 Biomass Maine 0.5 Dropped

- Onsite Unit

Perma Treat Corporation 10053 DG2 Combustion Turbine Maine 0.5 Dropped

- Onsite Unit

Pakini Nui Wind Farm 56378 1 Wind Hawaii 21 Dropped

- in Alaska or in Hawaii

Atlanta Gift Mart LP 54877 BUG Combustion Turbine Georgia 1.2 Dropped

- Onsite Unit

Port Arthur Texas Refinery 10568 GEN1 Combustion Turbine Texas 28.4 Dropped

- Onsite Unit

Aurora Energy LLC Chena 79 1 Coal Steam Alaska 6 Dropped

- in Alaska or in Hawaii

Aurora Energy LLC Chena 79 2 Coal Steam Alaska 2.5 Dropped

- in Alaska or in Hawaii

Aurora Energy LLC Chena 79 5 Coal Steam Alaska 23.9 Dropped

- in Alaska or in Hawaii

B Braun Medical 50200 GEN1 Combustion Turbine California 2.7 Dropped

- Onsite Unit

B Braun Medical 50200 GEN2 Combustion Turbine California 3 Dropped

- Onsite Unit

Geismar 10319 GEN1 Combustion Turbine Louisiana 33.7 Dropped

- Onsite Unit

Geismar 10319 GEN2 Combustion Turbine Louisiana 39.2 Dropped

- Onsite Unit

Geismar 10319 GEN3 O/G Steam Louisiana 7.2 Dropped

- Onsite Unit

BASF Freeport Works 55311 GEN1 Combustion Turbine Texas 75 Dropped

- Onsite Unit

BASF Freeport Works 55311 GEN2 O/G Steam Texas 11.7 Dropped

- Onsite Unit

Barrow 7173 10 Combustion Turbine Alaska 1.5 Dropped

- in Alaska or in Hawaii

Barrow 7173 11 Combustion Turbine Alaska 4.8 Dropped

- in Alaska or in Hawaii

Barrow 7173 12 Combustion Turbine Alaska 5 Dropped

- in Alaska or in Hawaii

## 107 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Barrow 7173 6 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Barrow 7173 7 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Barrow 7173 8 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Barrow 7173 9 Combustion Turbine Alaska 1.5 Dropped

- in Alaska or in Hawaii

Bassett Healthcare 54863 1 Combustion Turbine New York 0.8 Dropped

- Onsite Unit

Bassett Healthcare 54863 2 Combustion Turbine New York 0.8 Dropped

- Onsite Unit

Bassett Healthcare 54863 3 Combustion Turbine New York 0.8 Dropped

- Onsite Unit

Bassett Healthcare 54863 4 Combustion Turbine New York 1.6 Dropped

- Onsite Unit

Bassett Healthcare 54863 5 Combustion Turbine New York 2 Dropped

- Onsite Unit

Bethel 6566 1 Combustion Turbine Alaska 2.1 Dropped

- in Alaska or in Hawaii

Bethel 6566 2 Combustion Turbine Alaska 2.1 Dropped

- in Alaska or in Hawaii

Bethel 6566 3 Combustion Turbine Alaska 2.1 Dropped

- in Alaska or in Hawaii

Bethel 6566 4 Combustion Turbine Alaska 2.1 Dropped

- in Alaska or in Hawaii

Bethel 6566 6 Combustion Turbine Alaska 2.1 Dropped

- in Alaska or in Hawaii

Bethel 6566 7 Combustion Turbine Alaska 2.1 Dropped

- in Alaska or in Hawaii

Biola University 54296 EG1 Combustion Turbine California 0.6 Dropped

- Onsite Unit

Biola University 54296 EG2 Combustion Turbine California 0.6 Dropped

- Onsite Unit

Biola University 54296 EG3 Combustion Turbine California 1 Dropped

- Onsite Unit

DeRidder Mill 10488 TG Non

- Fossil Waste Louisiana 61.5 Dropped

- Onsite Unit

Bob Jones University Cogen Plant 10280 ENG1 Combustion Turbine South Carolina 1.1 Dropped

- Onsite Unit

Bob Jones University Cogen Plant 10280 ENG2 Combustion Turbine South Carolina 1.1 Dropped

- Onsite Unit

Bob Jones University Cogen Plant 10280 ENG3 Combustion Turbine South Carolina 1.1 Dropped

- Onsite Unit

Bob Jones University Cogen Plant 10280 ENG4 Combustion Turbine South Carolina 1.1 Dropped

- Onsite Unit

Bob Jones University Cogen Plant 10280 ENG5 Combustion Turbine South Carolina 1 Dropped

- Onsite Unit

Bob Jones University Cogen Plant 10280 ENG6 Combustion Turbine South Carolina 1 Dropped

- Onsite Unit

Bob Jones University Cogen Plant 10280 ENG7 Combustion Turbine South Carolina 1 Dropped

- Onsite Unit

Boise Cascade International Falls 10486 GEN1 O/G Steam Minnesota 4 Dropped

- Onsite Unit

Boise Cascade International Falls 10486 GEN2 O/G Steam Minnesota 4 Dropped

- Onsite Unit

Boise Cascade International Falls 10486 GEN3 O/G Steam Minnesota 7.5 Dropped

- Onsite Unit

Boise Cascade International Falls 10486 GEN4 O/G Steam Minnesota 7.5 Dropped

- Onsite Unit

## 108 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Boise Cascade International Falls 10486 GEN5 O/G Steam Minnesota 6.2 Dropped

- Onsite Unit

International Falls Power 10487 GEN1 Hydro Minnesota 2.2 Dropped

- Onsite Unit

International Falls Power 10487 GEN2 Hydro Minnesota 2.2 Dropped

- Onsite Unit

International Falls Power 10487 GEN3 Hydro Minnesota 2.2 Dropped

- Onsite Unit

International Falls Power 10487 GEN4 Hydro Minnesota 2.2 Dropped

- Onsite Unit

International Falls Power 10487 GEN5 Hydro Minnesota 2.2 Dropped

- Onsite Unit

International Falls Power 10487 GEN6 Hydro Minnesota 1.6 Dropped

- Onsite Unit

International Falls Power 10487 GEN7 Hydro Minnesota 1.6 Dropped

- Onsite Unit

U S Alliance Coosa Pines 54216 AOW6 Coal Steam Alabama 11.6 Dropped

- Onsite Unit

U S Alliance Coosa Pines 54216 GEN7 Non

- Fossil Waste Alabama 15 Dropped

- Onsite Unit

Alliance Refinery 52031 GEN1 Combustion Turbine Louisiana 6 Dropped

- Onsite Unit

Alliance Refinery 52031 GEN2 O/G Steam Louisiana 19 Dropped

- Onsite Unit

Bristol Myers Squibb 54829 GEN1 Combustion Turbine New Jersey 8.8 Dropped

- Onsite Unit

Bristol Myers Squibb 54829 GEN2 O/G Steam New Jersey 0.6 Dropped

- Onsite Unit

Brooklyn 1128 1 Combustion Turbine Iowa 0.2 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Brooklyn 1128 2 Combustion Turbine Iowa 0.2 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Brooklyn 1128 3 Combustion Turbine Iowa 0.2 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Brooklyn 1128 5 Combustion Turbine Iowa 1 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Brown University Central Heating 51029 EMG1 O/G Steam Rhode Island 3 Dropped

- Onsite Unit

Bunge Oil 52034 1 Combustion Turbine Illinois 2.8 Dropped

- Onsite Unit

Glines Hydroelectric Project 54050 GEN1 Hydro Washington 6 Dropped

- Onsite Unit

Elwha Hydroelectric Project 54051 GEN1 Hydro Washington 3 Dropped

- Onsite Unit

Elwha Hydroelectric Project 54051 GEN2 Hydro Washington 3 Dropped

- Onsite Unit

Elwha Hydroelectric Project 54051 GEN3 Hydro Washington 3.2 Dropped

- Onsite Unit

Elwha Hydroelectric Project 54051 GEN4 Hydro Washington 3.3 Dropped

- Onsite Unit

Buckeye Florida LP 50466 GEN2 Non

- Fossil Waste Florida 6.7 Dropped

- Onsite Unit

Buckeye Florida LP 50466 GEN3 Non

- Fossil Waste Florida 9.7 Dropped

- Onsite Unit

Buckeye Florida LP 50466 GEN4 Non

- Fossil Waste Florida 12.2 Dropped

- Onsite Unit

Buckeye Florida LP 50466 GEN5 Non

- Fossil Waste Florida 9.3 Dropped

- Onsite Unit

Sherwin Alumina 54291 1 Non

- Fossil Waste Texas 6 Dropped

- Onsite Unit

## 109 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Sherwin Alumina 54291 2 Non

- Fossil Waste Texas 6 Dropped

- Onsite Unit

Sherwin Alumina 54291 3 Non

- Fossil Waste Texas 6 Dropped

- Onsite Unit

Sherwin Alumina 54291 4 Non

- Fossil Waste Texas 6 Dropped

- Onsite Unit

BP Carson Refinery 50540 GEN1 Non

- Fossil Waste California 6.5 Dropped

- Onsite Unit

BP Carson Refinery 50540 GEN2 O/G Steam California 1.5 Dropped

- Onsite Unit

Cargill Salt 54965 ACTG Coal Steam Michigan 2 Dropped

- Onsite Unit

Richard J Donovan Correctional Facility 54936 3 Combustion Turbine California 2.2 Dropped

- Onsite Unit

Naval Hospital Medical Center 50963 4TG Combustion Turbine California 4.4 Dropped

- Onsite Unit

California Institute of Technology 10262 GEN6 Combined Cycle California 9 Dropped

- Onsite Unit

California Institute of Technology 10262 GEN7 Combined Cycle California 2.1 Dropped

- Onsite Unit

Rittman Paperboard 54235 GEN1 Coal Steam Ohio 3 Dropped

- Onsite Unit

Rittman Paperboard 54235 GEN2 Coal Steam Ohio 5 Dropped

- Onsite Unit

Rittman Paperboard 54235 GEN3 Coal Steam Ohio 6 Dropped

- Onsite Unit

Lee 2709 1 Coal Steam North Carolina 74 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Lee 2709 2 Coal Steam North Carolina 77 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Lee 2709 3 Coal Steam North Carolina 240 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

W H Weatherspoon 2716 1 Coal Steam North Carolina 48 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

W H Weatherspoon 2716 2 Coal Steam North Carolina 48 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

W H Weatherspoon 2716 3 Coal Steam North Carolina 74 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Cargill Corn Wet Milling Plant 10729 GEN1 Coal Steam Tennessee 10.3 Dropped

- Onsite Unit

Cargill Corn Milling Division 10855 GEN1 Coal Steam Iowa 18.7 Dropped

- Onsite Unit

Cargill Corn Milling Division 10855 GEN2 Coal Steam Iowa 18 Dropped

- Onsite Unit

Caterpillar 50935 3512 Combustion Turbine Indiana 0.8 Dropped

- Onsite Unit

Caterpillar 50935 3516 Combustion Turbine Indiana 0.8 Dropped

- Onsite Unit

Caterpillar 50935 516A Combustion Turbine Indiana 1.8 Dropped

- Onsite Unit

Caterpillar 50935 R12 Combustion Turbine Indiana 0.3 Dropped

- Onsite Unit

Bunge North America East LLC 50316 3516 Coal Steam Indiana 2.2 Dropped

- Onsite Unit

Central Michigan University 56190 GT1 Combustion Turbine Michigan 3.2 Dropped

- Onsite Unit

Central Michigan University 56190 STM1 Biomass Michigan 1 Dropped

- Onsite Unit

El Segundo Cogen 10213 GEN1 Combined Cycle California 38.7 Dropped

- Onsite Unit

## 110 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

El Segundo Cogen 10213 GEN2 Combined Cycle California 38.7 Dropped

- Onsite Unit

El Segundo Cogen 10213 GEN3 Combined Cycle California 1 Dropped

- Onsite Unit

El Segundo Cogen 10213 GEN4 Combined Cycle California 1 Dropped

- Onsite Unit

El Segundo Cogen 10213 GEN5 Combined Cycle California 39.2 Dropped

- Onsite Unit

El Segundo Cogen 10213 GEN6 Combined Cycle California 9.1 Dropped

- Onsite Unit

Hawaii Cogen 10194 GEN1 Fossil Waste Hawaii 3 Dropped

- Onsite Unit

Hawaii Cogen 10194 GEN2 Fossil Waste Hawaii 3 Dropped

- Onsite Unit

Hawaii Cogen 10194 GEN3 Fossil Waste Hawaii 3 Dropped

- Onsite Unit

Oak Point Cogen 55857 5121 Combustion Turbine Louisiana 4 Dropped

- Onsite Unit

Oak Point Cogen 55857 5131 Combustion Turbine Louisiana 4 Dropped

- Onsite Unit

Oak Point Cogen 55857 5141 Combustion Turbine Louisiana 4 Dropped

- Onsite Unit

Oak Point Cogen 55857 5151 Combustion Turbine Louisiana 4 Dropped

- Onsite Unit

Oak Point Cogen 55857 5161 Combustion Turbine Louisiana 4 Dropped

- Onsite Unit

Pascagoula Cogen 52084 TG1 Fossil Waste Mississippi 4 Dropped

- Onsite Unit

Beluga 96 1 Combustion Turbine Alaska 18.9 Dropped

- in Alaska or in Hawaii

Beluga 96 2 Combustion Turbine Alaska 18.9 Dropped

- in Alaska or in Hawaii

Beluga 96 3 Combustion Turbine Alaska 58 Dropped

- in Alaska or in Hawaii

Beluga 96 5 Combustion Turbine Alaska 61.4 Dropped

- in Alaska or in Hawaii

Beluga 96 6 Combined Cycle Alaska 72.6 Dropped

- in Alaska or in Hawaii

Beluga 96 7 Combined Cycle Alaska 70.6 Dropped

- in Alaska or in Hawaii

Beluga 96 8 Combined Cycle Alaska 44 Dropped

- in Alaska or in Hawaii

Cooper Lake 6291 1 Hydro Alaska 9.7 Dropped

- in Alaska or in Hawaii

Cooper Lake 6291 2 Hydro Alaska 9.7 Dropped

- in Alaska or in Hawaii

Bernice Lake 6292 2 Combustion Turbine Alaska 17 Dropped

- in Alaska or in Hawaii

Bernice Lake 6292 3 Combustion Turbine Alaska 22.9 Dropped

- in Alaska or in Hawaii

Bernice Lake 6292 4 Combustion Turbine Alaska 22.5 Dropped

- in Alaska or in Hawaii

International 6293 1 Combustion Turbine Alaska 12.6 Dropped

- in Alaska or in Hawaii

International 6293 2 Combustion Turbine Alaska 12.6 Dropped

- in Alaska or in Hawaii

International 6293 3 Combustion Turbine Alaska 16.7 Dropped

- in Alaska or in Hawaii

CC Perry K 992 4 Coal Steam Indiana 10 Dropped

- Onsite Unit

## 111 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

CC Perry K 992 6 Coal Steam Indiana 3 Dropped

- Onsite Unit

CC Perry K 992 7 Coal Steam Indiana 1.7 Dropped

- Onsite Unit

CC Perry K 992 8 Coal Steam Indiana 1.7 Dropped

- Onsite Unit

Puna Geothermal Venture I 52028 OEC11 Geothermal Hawaii 3.1 Dropped

- in Alaska or in Hawaii

Puna Geothermal Venture I 52028 OEC12 Geothermal Hawaii 3.1 Dropped

- in Alaska or in Hawaii

Puna Geothermal Venture I 52028 OEC13 Geothermal Hawaii 3.1 Dropped

- in Alaska or in Hawaii

Puna Geothermal Venture I 52028 OEC14 Geothermal Hawaii 3.1 Dropped

- in Alaska or in Hawaii

Puna Geothermal Venture I 52028 OEC15 Geothermal Hawaii 3.1 Dropped

- in Alaska or in Hawaii

Puna Geothermal Venture I 52028 OEC21 Geothermal Hawaii 3.1 Dropped

- in Alaska or in Hawaii

Puna Geothermal Venture I 52028 OEC22 Geothermal Hawaii 3.1 Dropped

- in Alaska or in Hawaii

Puna Geothermal Venture I 52028 OEC23 Geothermal Hawaii 3.1 Dropped

- in Alaska or in Hawaii

Puna Geothermal Venture I 52028 OEC24 Geothermal Hawaii 3.1 Dropped

- in Alaska or in Hawaii

Puna Geothermal Venture I 52028 OEC25 Geothermal Hawaii 3.1 Dropped

- in Alaska or in Hawaii

Florida's Natural Growers 10275 CE50 Combustion Turbine Florida 3.2 Dropped

- Onsite Unit

Florida's Natural Growers 10275 TA70 Combustion Turbine Florida 5.3 Dropped

- Onsite Unit

Chino Mines 54667 7 Combined Cycle New Mexico 15.4 Dropped

- Onsite Unit

Chino Mines 54667 9 Combined Cycle New Mexico 35 Dropped

- Onsite Unit

Clark University 10408 GEN1 Combustion Turbine Massachusetts 1.8 Dropped

- Onsite Unit

Bank of America Plaza 55152 GEN1 Combustion Turbine Georgia 1.3 Dropped

- Onsite Unit

Bank of America Plaza 55152 GEN2 Combustion Turbine Georgia 1.3 Dropped

- Onsite Unit

Colonial Sugar Refinery 10301 GEN1 O/G Steam Louisiana 0.6 Dropped

- Onsite Unit

Colonial Sugar Refinery 10301 GEN2 O/G Steam Louisiana 1.7 Dropped

- Onsite Unit

Colonial Sugar Refinery 10301 GEN3 O/G Steam Louisiana 1.5 Dropped

- Onsite Unit

Colonial Sugar Refinery 10301 GEN4 O/G Steam Louisiana 2.1 Dropped

- Onsite Unit

Hewlett Packard Alpharetta 54457 ALF1 Combustion Turbine Georgia 1 Dropped

- Onsite Unit

Hewlett Packard Alpharetta 54457 ALF2 Combustion Turbine Georgia 1 Dropped

- Onsite Unit

Hewlett Packard Alpharetta 54457 ALF3 Combustion Turbine Georgia 1 Dropped

- Onsite Unit

Hewlett Packard Alpharetta 54457 ALF4 Combustion Turbine Georgia 1 Dropped

- Onsite Unit

Hewlett Packard Alpharetta 54457 ALF5 Combustion Turbine Georgia 1 Dropped

- Onsite Unit

Hewlett Packard Alpharetta 54457 B1GN1 Combustion Turbine Georgia 1.4 Dropped

- Onsite Unit

## 112 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Hewlett Packard Alpharetta 54457 B1GN2 Combustion Turbine Georgia 1.4 Dropped

- Onsite Unit

Heat Recovery Coke Facility 55066 TG18 Non

- Fossil Waste Indiana 88 Dropped

- Onsite Unit

Solomon Gulch 390 1 Hydro Alaska 6 Dropped

- in Alaska or in Hawaii

Solomon Gulch 390 2 Hydro Alaska 6 Dropped

- in Alaska or in Hawaii

Glennallen 6305 3 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Glennallen 6305 4 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Glennallen 6305 5 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Glennallen 6305 6 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Glennallen 6305 7 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Glennallen 6305 8 Combustion Turbine Alaska 1.2 Dropped

- in Alaska or in Hawaii

Glennallen 6305 9 Combustion Turbine Alaska 2.8 Dropped

- in Alaska or in Hawaii

Valdez 6306 1 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Valdez 6306 2 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Valdez 6306 3 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Valdez 6306 4 Combustion Turbine Alaska 1.5 Dropped

- in Alaska or in Hawaii

Valdez 6306 5 Combustion Turbine Alaska 2 Dropped

- in Alaska or in Hawaii

Valdez 6306 6 Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

Valdez 6306 7 Combustion Turbine Alaska 2.8 Dropped

- in Alaska or in Hawaii

Valdez Cogen 7841 1 Combustion Turbine Alaska 5.1 Dropped

- in Alaska or in Hawaii

Corn Products Stockton Plant 52115 GEN1 Combustion Turbine California 2.8 Dropped

- Onsite Unit

Anderson Power Products Division 10553 3622 Combustion Turbine Massachusetts 0.1 Dropped

- Onsite Unit

Anderson Power Products Division 10553 6033 Combustion Turbine Massachusetts 0.3 Dropped

- Onsite Unit

Anderson Power Products Division 10553 6035 Combustion Turbine Massachusetts 0.3 Dropped

- Onsite Unit

Anderson Power Products Division 10553 6046 Combustion Turbine Massachusetts 0.3 Dropped

- Onsite Unit

Cornell Hydro 10286 1 Hydro New York 0.5 Dropped

- Onsite Unit

Cornell Hydro 10286 2 Hydro New York 1.1 Dropped

- Onsite Unit

Corn Products Winston Salem 54618 7500 Biomass North Carolina 6.6 Dropped

- Onsite Unit

Corn Products Winston Salem 54618 900 Biomass North Carolina 0.4 Dropped

- Onsite Unit

Cutrale Citrus Juices USA I 10020 GEN1 Combustion Turbine Florida 3.1 Dropped

- Onsite Unit

Cutrale Citrus Juices USA II 10188 GEN1 Combined Cycle Florida 3 Dropped

- Onsite Unit

## 113 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Cutrale Citrus Juices USA II 10188 GEN2 Combined Cycle Florida 3 Dropped

- Onsite Unit

Cutrale Citrus Juices USA II 10188 GEN3 Combined Cycle Florida 1.3 Dropped

- Onsite Unit

Crotched Mountain Rehabilitation Center 54515 GEN1 Combustion Turbine New Hampshire 0.7 Dropped

- Onsite Unit

Crotched Mountain Rehabilitation Center 54515 GEN2 Combustion Turbine New Hampshire 0.7 Dropped

- Onsite Unit

Crotched Mountain Rehabilitation Center 54515 GEN3 Combustion Turbine New Hampshire 0.7 Dropped

- Onsite Unit

Georgia Pacific Crossett 10606 GEN4 Non

- Fossil Waste Arkansas 28 Dropped

- Onsite Unit

Georgia Pacific Crossett 10606 GEN5 Non

- Fossil Waste Arkansas 30 Dropped

- Onsite Unit

Georgia Pacific Crossett 10606 GEN6 Non

- Fossil Waste Arkansas 34 Dropped

- Onsite Unit

Dartmouth College Heating Plant 54409 GEN1 O/G Steam New Hampshire 2 Dropped

- Onsite Unit

Dartmouth College Heating Plant 54409 GEN2 O/G Steam New Hampshire 2 Dropped

- Onsite Unit

Dartmouth College Heating Plant 54409 GEN3 O/G Steam New Hampshire 3 Dropped

- Onsite Unit

Aniak 7182 1 Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Aniak 7182 9 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

Georgia

- Pacific Corp

- Nekoosa Mill 50395 HY1 Hydro Wisconsin 0.8 Dropped

- Onsite Unit

Georgia

- Pacific Corp

- Nekoosa Mill 50395 HY2 Hydro Wisconsin 0.8 Dropped

- Onsite Unit

Georgia

- Pacific Corp

- Nekoosa Mill 50395 HY3 Hydro Wisconsin 0.8 Dropped

- Onsite Unit

Georgia

- Pacific Corp

- Nekoosa Mill 50395 HY4 Hydro Wisconsin 0.6 Dropped

- Onsite Unit

Georgia

- Pacific Corp

- Nekoosa Mill 50395 HY5 Hydro Wisconsin 0.7 Dropped

- Onsite Unit

Georgia

- Pacific Corp

- Nekoosa Mill 50395 NHG1 Hydro Wisconsin 0.2 Dropped

- Onsite Unit

Georgia

- Pacific Corp

- Nekoosa Mill 50395 TG14 Non

- Fossil Waste Wisconsin 12.5 Dropped

- Onsite Unit

Georgia

- Pacific Corp

- Nekoosa Mill 50395 TG6 Coal Steam Wisconsin 5.7 Dropped

- Onsite Unit

Georgia

- Pacific Corp

- Nekoosa Mill 50395 TG8 Coal Steam Wisconsin 13 Dropped

- Onsite Unit

Des Moines Wastewater Reclamation Fac 50932 1 Non

- Fossil Waste Iowa 0.6 Dropped

- Onsite Unit

Des Moines Wastewater Reclamation Fac 50932 2 Non

- Fossil Waste Iowa 0.6 Dropped

- Onsite Unit

Des Moines Wastewater Reclamation Fac 50932 3 Non

- Fossil Waste Iowa 0.6 Dropped

- Onsite Unit

Beaver Creek Gas Plant 55278 1 Combustion Turbine Wyoming 1.8 Dropped

- Onsite Unit

Beaver Creek Gas Plant 55278 2 Combustion Turbine Wyoming 1.8 Dropped

- Onsite Unit

Ashdown 54104 GEN1 Non

- Fossil Waste Arkansas 17 Dropped

- Onsite Unit

Ashdown 54104 GEN2 Non

- Fossil Waste Arkansas 40 Dropped

- Onsite Unit

Ashdown 54104 GEN3 Non

- Fossil Waste Arkansas 33 Dropped

- Onsite Unit

## 114 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Ashdown 54104 GEN4 Non

- Fossil Waste Arkansas 38 Dropped

- Onsite Unit

Domino Sugar Baltimore 54795 GEN1 O/G Steam Maryland 5 Dropped

- Onsite Unit

Domino Sugar Baltimore 54795 GEN2 O/G Steam Maryland 2.5 Dropped

- Onsite Unit

Domino Sugar Baltimore 54795 GEN4 O/G Steam Maryland 10 Dropped

- Onsite Unit

ABC Coke 56076 1 Fossil Waste Alabama 3.8 Dropped

- Onsite Unit

Dow Chemical Texas Operation 52120 G

- 35 Combined Cycle Texas 95.6 Dropped

- Onsite Unit

Dow Chemical Texas Operation 52120 G

- 36 Combined Cycle Texas 99 Dropped

- Onsite Unit

Dow Chemical Texas Operation 52120 G

- 37 Combined Cycle Texas 59.2 Dropped

- Onsite Unit

Dow Chemical Texas Operation 52120 G

- 61 Combined Cycle Texas 68.3 Dropped

- Onsite Unit

Dow Chemical Texas Operation 52120 G

- 62 Combined Cycle Texas 68.3 Dropped

- Onsite Unit

Dow Chemical Texas Operation 52120 G

- 63 Combined Cycle Texas 68.3 Dropped

- Onsite Unit

Dow Chemical Texas Operation 52120 G

- 64 Combined Cycle Texas 50 Dropped

- Onsite Unit

Dow Chemical Texas Operation 52120 G

- 65 Combined Cycle Texas 95.2 Dropped

- Onsite Unit

Dow Chemical Texas Operation 52120 G

- 66 Combined Cycle Texas 95.6 Dropped

- Onsite Unit

Dow Chemical Texas Operation 52120 G

- 67 Combined Cycle Texas 95.6 Dropped

- Onsite Unit

La o Energy Systems 52006 GEN1 Combined Cycle Louisiana 57 Dropped

- Onsite Unit

La o Energy Systems 52006 GEN2 Combined Cycle Louisiana 80 Dropped

- Onsite Unit

La o Energy Systems 52006 GEN3 Combined Cycle Louisiana 94 Dropped

- Onsite Unit

La o Energy Systems 52006 GEN4 Combined Cycle Louisiana 49 Dropped

- Onsite Unit

La o Energy Systems 52006 GEN5 Combined Cycle Louisiana 52 Dropped

- Onsite Unit

La o Energy Systems 52006 GEN6 Combined Cycle Louisiana 52 Dropped

- Onsite Unit

La o Energy Systems 52006 GEN7 Combined Cycle Louisiana 95 Dropped

- Onsite Unit

La o Energy Systems 52006 GEN8 Combined Cycle Louisiana 95 Dropped

- Onsite Unit

Buck 2720 3 Coal Steam North Carolina 75 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buck 2720 4 Coal Steam North Carolina 38 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buck 2720 5 Coal Steam North Carolina 128 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buck 2720 6 Coal Steam North Carolina 128 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buck 2720 7 Combustion Turbine North Carolina 25 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buck 2720 8 Combustion Turbine North Carolina 25 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buck 2720 9 Combustion Turbine North Carolina 12 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

## 115 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Cliffside 2721 1 Coal Steam North Carolina 38 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Cliffside 2721 2 Coal Steam North Carolina 38 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Cliffside 2721 3 Coal Steam North Carolina 61 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Cliffside 2721 4 Coal Steam North Carolina 61 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Dan River 2723 1 Coal Steam North Carolina 67 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Dan River 2723 2 Coal Steam North Carolina 67 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Dan River 2723 3 Coal Steam North Carolina 142 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Dan River 2723 4 Combustion Turbine North Carolina 24 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Dan River 2723 5 Combustion Turbine North Carolina 24 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Dan River 2723 6 Combustion Turbine North Carolina 24 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Riverbend 2732 10 Combustion Turbine North Carolina 22 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Riverbend 2732 11 Combustion Turbine North Carolina 20 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Riverbend 2732 4 Coal Steam North Carolina 94 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Riverbend 2732 5 Coal Steam North Carolina 94 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Riverbend 2732 6 Coal Steam North Carolina 133 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Riverbend 2732 7 Coal Steam North Carolina 133 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Riverbend 2732 8 Combustion Turbine North Carolina 20 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Riverbend 2732 9 Combustion Turbine North Carolina 22 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Roost 3254 10 Combustion Turbine South Carolina 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Roost 3254 11 Combustion Turbine South Carolina 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Roost 3254 12 Combustion Turbine South Carolina 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Roost 3254 13 Combustion Turbine South Carolina 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Roost 3254 14 Combustion Turbine South Carolina 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Roost 3254 15 Combustion Turbine South Carolina 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Roost 3254 6 Combustion Turbine South Carolina 20 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Roost 3254 7 Combustion Turbine South Carolina 20 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Roost 3254 8 Combustion Turbine South Carolina 20 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Roost 3254 9 Combustion Turbine South Carolina 20 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Durgin & Crowell Lumber 54870 3306 Combustion Turbine New Hampshire 0.2 Dropped

- Onsite Unit

Durgin & Crowell Lumber 54870 3512 Combustion Turbine New Hampshire 1.3 Dropped

- Onsite Unit

## 116 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Woodridge Greene Valley Treatment Plant 54987 FM01 Combustion Turbine Illinois 1.5 Dropped

- Onsite Unit

Stingray Facility 54531 1S72 Combustion Turbine Louisiana 2.5 Dropped

- Onsite Unit

ExxonMobil Oil Joliet Refinery 50627 GTG1 Fossil Waste Illinois 22 Dropped

- Onsite Unit

ExxonMobil Oil Joliet Refinery 50627 MG Fossil Waste Illinois 11.2 Dropped

- Onsite Unit

ExxonMobil Oil Joliet Refinery 50627 STG1 Fossil Waste Illinois 6.5 Dropped

- Onsite Unit

DSM Pharmaceuticals 54887 GEN1 Combustion Turbine North Carolina 3.5 Dropped

- Onsite Unit

DSM Pharmaceuticals 54887 GEN2 Combustion Turbine North Carolina 0.3 Dropped

- Onsite Unit

DSM Pharmaceuticals 54887 GEN3 Combustion Turbine North Carolina 1.1 Dropped

- Onsite Unit

DSM Pharmaceuticals 54887 GEN4 Combustion Turbine North Carolina 1.2 Dropped

- Onsite Unit

DSM Pharmaceuticals 54887 GEN5 Combustion Turbine North Carolina 1 Dropped

- Onsite Unit

DSM Pharmaceuticals 54887 GEN6 Combustion Turbine North Carolina 1.2 Dropped

- Onsite Unit

Sabine River Works 10789 GEN1 Combined Cycle Texas 82 Dropped

- Onsite Unit

Sabine River Works 10789 GEN3 Combined Cycle Texas 5 Dropped

- Onsite Unit

Sabine River Works 10789 GEN4 Combined Cycle Texas 5 Dropped

- Onsite Unit

Old Hickory Plant 10797 IG O/G Steam Tennessee 1 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TG10 Coal Steam Tennessee 6 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TG11 Coal Steam Tennessee 6 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TG12 Coal Steam Tennessee 6 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TG13 Coal Steam Tennessee 7 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TG14 Coal Steam Tennessee 10 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TG15 Coal Steam Tennessee 7.5 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TG16 Coal Steam Tennessee 10.4 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TG17 Coal Steam Tennessee 10.4 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TG18 Coal Steam Tennessee 10.4 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TG19 Coal Steam Tennessee 10.4 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TG20 Coal Steam Tennessee 10.4 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TG21 Coal Steam Tennessee 15 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TG22 Coal Steam Tennessee 15.4 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TG24 Coal Steam Tennessee 16.8 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TG25 Coal Steam Tennessee 18 Dropped

- Onsite Unit

## 117 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Tennessee Eastman Operations 50481 TG26 Coal Steam Tennessee 16.6 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TGO7 Coal Steam Tennessee 6 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TGO8 Coal Steam Tennessee 6 Dropped

- Onsite Unit

Tennessee Eastman Operations 50481 TGO9 Coal Steam Tennessee 6 Dropped

- Onsite Unit

Eastman Gelatine 50955 GEN1 O/G Steam Massachusetts 1.3 Dropped

- Onsite Unit

Eastman Gelatine 50955 GEN2 O/G Steam Massachusetts 1.5 Dropped

- Onsite Unit

Eastman Gelatine 50955 GEN3 O/G Steam Massachusetts 3.3 Dropped

- Onsite Unit

Kodak Park Site 10025 17TG Coal Steam New York 15 Dropped

- Onsite Unit

Kodak Park Site 10025 22TG Coal Steam New York 12.5 Dropped

- Onsite Unit

Kodak Park Site 10025 41TG Coal Steam New York 25.6 Dropped

- Onsite Unit

Kodak Park Site 10025 42TG Coal Steam New York 25.6 Dropped

- Onsite Unit

Kodak Park Site 10025 43TG Coal Steam New York 25.6 Dropped

- Onsite Unit

Kodak Park Site 10025 44TG Coal Steam New York 25.6 Dropped

- Onsite Unit

Kodak Park Site 10025 KPR1 Hydro New York 0.4 Dropped

- Onsite Unit

Rio Grande 2444 6 O/G Steam New Mexico 45 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Newman 3456 2 O/G Steam Texas 76 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Encina Water Pollution Control 10026 EG10 Non

- Fossil Waste California 0.8 Dropped

- Onsite Unit

Encina Water Pollution Control 10026 EG20 Non

- Fossil Waste California 0.8 Dropped

- Onsite Unit

Encina Water Pollution Control 10026 EG30 Non

- Fossil Waste California 0.8 Dropped

- Onsite Unit

Encina Water Pollution Control 10026 EG40 Non

- Fossil Waste California 0.8 Dropped

- Onsite Unit

Hawi Wind Farm 56447 V

- 47 Wind Hawaii 10.6 Dropped

- in Alaska or in Hawaii

Erie Coke 50920 1 Fossil Waste Pennsylvania 1 Dropped

- Onsite Unit

Erving Paper Mills 54228 1 O/G Steam Massachusetts 0.3 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Cromby Generating Station 3159 1 Coal Steam Pennsylvania 144 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Cromby Generating Station 3159 2 O/G Steam Pennsylvania 201 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Cromby Generating Station 3159 ICI Combustion Turbine Pennsylvania 2.7 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Eddystone Generating Station 3161 1 Coal Steam Pennsylvania 279 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Eddystone Generating Station 3161 2 Coal Steam Pennsylvania 309 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

ExxonMobil Baton Rouge Turbine Generator 10690 CTG1 Combustion Turbine Louisiana 76.7 Dropped

- Onsite Unit

ExxonMobil Baytown Refinery 10436 GT38 Combustion Turbine Texas 31 Dropped

- Onsite Unit

## 118 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

ExxonMobil Baytown Refinery 10436 GT41 Combustion Turbine Texas 17 Dropped

- Onsite Unit

ExxonMobil Baytown Refinery 10436 GT42 Combustion Turbine Texas 17 Dropped

- Onsite Unit

ExxonMobil Baytown Refinery 10436 GT43 Combustion Turbine Texas 17 Dropped

- Onsite Unit

ExxonMobil Baytown Refinery 10436 GT44 Combustion Turbine Texas 17 Dropped

- Onsite Unit

ExxonMobil Baytown Refinery 10436 GT45 Combustion Turbine Texas 31 Dropped

- Onsite Unit

ExxonMobil Baytown Refinery 10436 ST34 Non

- Fossil Waste Texas 7 Dropped

- Onsite Unit

ExxonMobil Baytown Turbine 10692 GEN1 Combustion Turbine Texas 31.7 Dropped

- Onsite Unit

ExxonMobil Baytown Turbine 10692 GEN2 Combustion Turbine Texas 31.7 Dropped

- Onsite Unit

ExxonMobil Baytown Turbine 10692 GEN3 Combustion Turbine Texas 31.7 Dropped

- Onsite Unit

ExxonMobil Baytown Turbine 10692 GEN4 Combustion Turbine Texas 85 Dropped

- Onsite Unit

ExxonMobil Baytown Turbine 10692 GEN5 Combustion Turbine Texas 140.3 Dropped

- Onsite Unit

Corpus Refinery 50026 FCCE Non

- Fossil Waste Texas 9.7 Dropped

- Onsite Unit

Corpus Refinery 50026 FR6 Combustion Turbine Texas 32 Dropped

- Onsite Unit

ExxonMobil Santa Ynez Facility 50270 GTG1 Combined Cycle California 40.2 Dropped

- Onsite Unit

ExxonMobil Santa Ynez Facility 50270 STG1 Combined Cycle California 8.9 Dropped

- Onsite Unit

Shute Creek Facility 56312 021A Fossil Waste Wyoming 30.6 Dropped

- Onsite Unit

Shute Creek Facility 56312 021B Fossil Waste Wyoming 30.6 Dropped

- Onsite Unit

Shute Creek Facility 56312 021C Fossil Waste Wyoming 30.6 Dropped

- Onsite Unit

Ford Motor Co Rawsonville Plant 10235 GEN1 Combustion Turbine Michigan 4.5 Dropped

- Onsite Unit

Formosa Utility Venture Ltd 10554 BO3 Combined Cycle Texas 32 Dropped

- Onsite Unit

Formosa Utility Venture Ltd 10554 ST1 Combined Cycle Texas 28.5 Dropped

- Onsite Unit

Formosa Utility Venture Ltd 10554 ST2 Combined Cycle Texas 57.5 Dropped

- Onsite Unit

Formosa Utility Venture Ltd 10554 ST3 Combined Cycle Texas 47.3 Dropped

- Onsite Unit

Formosa Utility Venture Ltd 10554 TBG1 Combined Cycle Texas 72 Dropped

- Onsite Unit

Formosa Utility Venture Ltd 10554 TBG2 Combined Cycle Texas 72 Dropped

- Onsite Unit

Formosa Utility Venture Ltd 10554 TBG3 Combined Cycle Texas 72 Dropped

- Onsite Unit

Formosa Utility Venture Ltd 10554 TBG4 Combined Cycle Texas 72 Dropped

- Onsite Unit

Formosa Utility Venture Ltd 10554 TBG5 Combined Cycle Texas 72 Dropped

- Onsite Unit

Formosa Utility Venture Ltd 10554 TBG6 Combined Cycle Texas 72 Dropped

- Onsite Unit

Muskogee Mill 10362 GEN1 Coal Steam Oklahoma 17 Dropped

- Onsite Unit

## 119 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Muskogee Mill 10362 GEN2 Coal Steam Oklahoma 18.3 Dropped

- Onsite Unit

Muskogee Mill 10362 GEN3 Coal Steam Oklahoma 34.2 Dropped

- Onsite Unit

Hampton Facility 10108 GEN1 Combustion Turbine New Hampshire 0.5 Dropped

- Onsite Unit

Hampton Facility 10108 GEN2 Combustion Turbine New Hampshire 0.5 Dropped

- Onsite Unit

Hampton Facility 10108 GEN3 Combustion Turbine New Hampshire 0.7 Dropped

- Onsite Unit

Hampton Facility 10108 GEN4 Combustion Turbine New Hampshire 0.7 Dropped

- Onsite Unit

Hampton Facility 10108 GEN5 Combustion Turbine New Hampshire 0.7 Dropped

- Onsite Unit

Hampton Facility 10108 GEN6 Combustion Turbine New Hampshire 0.7 Dropped

- Onsite Unit

Hampton Facility 10108 GEN8 Combustion Turbine New Hampshire 3.8 Dropped

- Onsite Unit

Ergon Refining Vicksburg 54918 TMO1 Combustion Turbine Mississippi 4.4 Dropped

- Onsite Unit

Fox Metro Water Reclamation District 50904 RU3 Combustion Turbine Illinois 1.1 Dropped

- Onsite Unit

Fox Metro Water Reclamation District 50904 RU4 Combustion Turbine Illinois 1.1 Dropped

- Onsite Unit

French Paper Hydro 10656 1 Hydro Michigan 0.3 Dropped

- Onsite Unit

French Paper Hydro 10656 2 Hydro Michigan 0.4 Dropped

- Onsite Unit

French Paper Hydro 10656 3 Hydro Michigan 0.3 Dropped

- Onsite Unit

French Paper Hydro 10656 4 Hydro Michigan 0.2 Dropped

- Onsite Unit

Village Creek Wastewater Treatment Plant 54520 SD2 Combustion Turbine Texas 0.9 Dropped

- Onsite Unit

Village Creek Wastewater Treatment Plant 54520 SDI Combustion Turbine Texas 0.9 Dropped

- Onsite Unit

Village Creek Wastewater Treatment Plant 54520 TG1 Non

- Fossil Waste Texas 4.2 Dropped

- Onsite Unit

Village Creek Wastewater Treatment Plant 54520 TG2 Non

- Fossil Waste Texas 4.2 Dropped

- Onsite Unit

Evanston Township High School 54788 GEN1 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Evanston Township High School 54788 GEN2 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Evanston Township High School 54788 GEN3 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Georgia Pacific Center 54906 1 Combustion Turbine Georgia 0.7 Dropped

- Onsite Unit

Georgia Pacific Center 54906 2 Combustion Turbine Georgia 0.7 Dropped

- Onsite Unit

Galena Electric Utility 7437 1A Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

Galena Electric Utility 7437 2 Combustion Turbine Alaska 0.7 Dropped

- in Alaska or in Hawaii

Galena Electric Utility 7437 3A Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

Galena Electric Utility 7437 4A Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Galena Electric Utility 7437 5A Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

## 120 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

C E Newman 3574 5 O/G Steam Texas 37 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Gallup Refinery 50997 GEN1 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Gallup Refinery 50997 GEN2 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Gay Robinson 50333 DSL5 Combustion Turbine Hawaii 0.5 Dropped

- in Alaska or in Hawaii

Gay Robinson 50333 DSL6 Combustion Turbine Hawaii 0.5 Dropped

- in Alaska or in Hawaii

Gay Robinson 50333 HYD2 Hydro Hawaii 0.8 Dropped

- in Alaska or in Hawaii

Gay Robinson 50333 ST4 Biomass Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Gaylord Container Bogalusa 54427 NO10 Biomass Louisiana 34.4 Dropped

- Onsite Unit

Gaylord Container Bogalusa 54427 NO8 Biomass Louisiana 23.3 Dropped

- Onsite Unit

Gaylord Container Bogalusa 54427 NO9 Biomass Louisiana 34.9 Dropped

- Onsite Unit

General Electric Aircraft Engines 10029 GEN5 O/G Steam Massachusetts 10 Dropped

- Onsite Unit

General Electric Aircraft Engines 10029 GEN6 O/G Steam Massachusetts 10 Dropped

- Onsite Unit

General Electric Aircraft Engines 10029 GEN7 O/G Steam Massachusetts 12.5 Dropped

- Onsite Unit

General Electric Aircraft Engines 10029 GEN8 Combustion Turbine Massachusetts 21.1 Dropped

- Onsite Unit

General Mills West Chicago 54924 1 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

General Mills West Chicago 54924 2 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

General Mills West Chicago 54924 3 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

General Mills West Chicago 54924 4 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

General Mills West Chicago 54924 5 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

General Mills West Chicago 54924 6 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

General Mills West Chicago 54924 7 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

General Mills West Chicago 54924 8 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

General Chemical 54318 TG1 Coal Steam Wyoming 15 Dropped

- Onsite Unit

General Chemical 54318 TG2 Coal Steam Wyoming 15 Dropped

- Onsite Unit

General Electric Diesel Engine Plant 10058 REGN Combustion Turbine Pennsylvania 4.3 Dropped

- Onsite Unit

General Mills Inc 54564 GEN1 Combustion Turbine New York 3.4 Dropped

- Onsite Unit

Savannah River Mill 10361 GEN1 Combustion Turbine Georgia 21.4 Dropped

- Onsite Unit

Savannah River Mill 10361 GEN2 Combustion Turbine Georgia 21.4 Dropped

- Onsite Unit

Savannah River Mill 10361 GEN3 Coal Steam Georgia 41.9 Dropped

- Onsite Unit

Savannah River Mill 10361 GEN4 Coal Steam Georgia 41.9 Dropped

- Onsite Unit

## 121 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Georgia Pacific Naheola Mill 10699 GEN1 Non

- Fossil Waste Alabama 14.5 Dropped

- Onsite Unit

Georgia Pacific Naheola Mill 10699 GEN2 Non

- Fossil Waste Alabama 14.5 Dropped

- Onsite Unit

Georgia Pacific Naheola Mill 10699 GT3 Non

- Fossil Waste Alabama 43.8 Dropped

- Onsite Unit

Tate & Lyle Decatur Plant Cogen 10867 GEN1 Coal Steam Illinois 58.1 Dropped

- Onsite Unit

Sagamore Plant Cogeneration 50903 GEN1 Coal Steam Indiana 7.4 Dropped

- Onsite Unit

Harllee Branch 709 1 Coal Steam Georgia 266 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Harllee Branch 709 2 Coal Steam Georgia 325 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Jack McDonough 710 1 Coal Steam Georgia 251 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Jack McDonough 710 2 Coal Steam Georgia 251 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Mitchell 727 4C Combustion Turbine Georgia 31 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Georgia Pacific Monticello Paper 10610 GEN1 Non

- Fossil Waste Mississippi 36 Dropped

- Onsite Unit

Georgia Pacific Monticello Paper 10610 GEN2 Non

- Fossil Waste Mississippi 32 Dropped

- Onsite Unit

Georgia Pacific Big Island 50479 BHG1 Hydro Virginia 0.2 Dropped

- Onsite Unit

Georgia Pacific Big Island 50479 BHG2 Hydro Virginia 0.2 Dropped

- Onsite Unit

Georgia Pacific Big Island 50479 GEN1 Biomass Virginia 6.5 Dropped

- Onsite Unit

CITGO Refinery Powerhouse 52175 GEN1 Fossil Waste Louisiana 7.4 Dropped

- Onsite Unit

CITGO Refinery Powerhouse 52175 GEN2 Fossil Waste Louisiana 9.4 Dropped

- Onsite Unit

CITGO Refinery Powerhouse 52175 GEN3 Fossil Waste Louisiana 17.5 Dropped

- Onsite Unit

Georgia Pacific Cedar Springs 54101 GEN1 Non

- Fossil Waste Georgia 45 Dropped

- Onsite Unit

Georgia Pacific Cedar Springs 54101 GEN2 Non

- Fossil Waste Georgia 45 Dropped

- Onsite Unit

General Mills Operations Lodi 10031 1 Combustion Turbine California 3.2 Dropped

- Onsite Unit

Romulus Operations Powertrain 10159 GEN1 Combustion Turbine Michigan 6 Dropped

- Onsite Unit

Gillette SBMC 54225 DG Combustion Turbine Massachusetts 0.5 Dropped

- Onsite Unit

Gillette SBMC 54225 DG2 Combustion Turbine Massachusetts 0.5 Dropped

- Onsite Unit

Gillette SBMC 54225 DG3 Combustion Turbine Massachusetts 1 Dropped

- Onsite Unit

Gillette SBMC 54225 TG1 O/G Steam Massachusetts 6.3 Dropped

- Onsite Unit

Gillette SBMC 54225 TG2 O/G Steam Massachusetts 5 Dropped

- Onsite Unit

Powertrain Warren General Motors 10032 GT1 Combustion Turbine Michigan 2.7 Dropped

- Onsite Unit

North Pole 6285 1 Combustion Turbine Alaska 48 Dropped

- in Alaska or in Hawaii

North Pole 6285 2 Combustion Turbine Alaska 48 Dropped

- in Alaska or in Hawaii

## 122 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

North Pole 6285 GT3 Combined Cycle Alaska 41 Dropped

- in Alaska or in Hawaii

North Pole 6285 STG1 Combined Cycle Alaska 7 Dropped

- in Alaska or in Hawaii

Fairbanks 6286 5 Combustion Turbine Alaska 2.8 Dropped

- in Alaska or in Hawaii

Fairbanks 6286 6 Combustion Turbine Alaska 2.8 Dropped

- in Alaska or in Hawaii

Fairbanks 6286 GT1 Combustion Turbine Alaska 16 Dropped

- in Alaska or in Hawaii

Fairbanks 6286 GT2 Combustion Turbine Alaska 16.3 Dropped

- in Alaska or in Hawaii

Healy 6288 1 Coal Steam Alaska 25 Dropped

- in Alaska or in Hawaii

Healy 6288 IC1 Combustion Turbine Alaska 2.8 Dropped

- in Alaska or in Hawaii

Delta Power 56325 6 Combustion Turbine Alaska 23.1 Dropped

- in Alaska or in Hawaii

Battery Energy Storage System 57583 BESS Non

- Fossil Waste Alaska 27 Dropped

- in Alaska or in Hawaii

Gowrie 1141 1 Combustion Turbine Iowa 1.1 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Gowrie 1141 2 Combustion Turbine Iowa 1.1 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Graphic Packaging 10698 GEN1 O/G Steam Michigan 5 Dropped

- Onsite Unit

Graphic Packaging 10698 GEN2 O/G Steam Michigan 1.5 Dropped

- Onsite Unit

Grossmont Hospital 10115 GEN1 Combustion Turbine California 0.8 Dropped

- Onsite Unit

Grossmont Hospital 10115 GEN2 Combustion Turbine California 0.8 Dropped

- Onsite Unit

Gwitchyaa Zhee 7174 1 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Gwitchyaa Zhee 7174 3 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Gwitchyaa Zhee 7174 6 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Cheboygan 50461 GEN1 Hydro Michigan 0.7 Dropped

- Onsite Unit

Hamakua Energy Plant 55369 CT1 Fossil Waste Hawaii 21.7 Dropped

- in Alaska or in Hawaii

Hamakua Energy Plant 55369 CT2 Fossil Waste Hawaii 21.7 Dropped

- in Alaska or in Hawaii

Hamakua Energy Plant 55369 ST1 Fossil Waste Hawaii 17.4 Dropped

- in Alaska or in Hawaii

International Paper Prattville Mill 52140 GEN1 Non

- Fossil Waste Alabama 31.1 Dropped

- Onsite Unit

International Paper Prattville Mill 52140 GEN2 Non

- Fossil Waste Alabama 44.9 Dropped

- Onsite Unit

Hawaiian Comm & Sugar Puunene Mill 10604 PUU3 Biomass Hawaii 10 Dropped

- in Alaska or in Hawaii

Hawaiian Comm & Sugar Puunene Mill 10604 PUU4 Biomass Hawaii 20 Dropped

- in Alaska or in Hawaii

Hawaiian Comm & Sugar Puunene Mill 10604 PUU5 Biomass Hawaii 16.1 Dropped

- in Alaska or in Hawaii

Kaheka Hydro 55864 KAH1 Hydro Hawaii 1.5 Dropped

- in Alaska or in Hawaii

Kaheka Hydro 55864 KAH2 Hydro Hawaii 1.5 Dropped

- in Alaska or in Hawaii

## 123 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Kaheka Hydro 55864 KAH3 Hydro Hawaii 1.5 Dropped

- in Alaska or in Hawaii

Waimea 768 12 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Waimea 768 13 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Waimea 768 14 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Kanoelehua 769 11 Combustion Turbine Hawaii 2 Dropped

- in Alaska or in Hawaii

Kanoelehua 769 15 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Kanoelehua 769 16 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Kanoelehua 769 17 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Kanoelehua 769 CT1 Combustion Turbine Hawaii 10.5 Dropped

- in Alaska or in Hawaii

Puueo 771 1 Hydro Hawaii 0.7 Dropped

- in Alaska or in Hawaii

Puueo 771 2A Hydro Hawaii 2.4 Dropped

- in Alaska or in Hawaii

W H Hill 772 5 O/G Steam Hawaii 14.1 Dropped

- in Alaska or in Hawaii

W H Hill 772 6 O/G Steam Hawaii 21.4 Dropped

- in Alaska or in Hawaii

Waiau 774 1 Hydro Hawaii 0.7 Dropped

- in Alaska or in Hawaii

Waiau 774 2 Hydro Hawaii 0.3 Dropped

- in Alaska or in Hawaii

Shipman 6478 3 O/G Steam Hawaii 7.5 Dropped

- in Alaska or in Hawaii

Shipman 6478 4 O/G Steam Hawaii 7.5 Dropped

- in Alaska or in Hawaii

Puna 7130 1 O/G Steam Hawaii 14 Dropped

- in Alaska or in Hawaii

Puna 7130 3 Combustion Turbine Hawaii 20 Dropped

- in Alaska or in Hawaii

Keahole 8083 2 Combustion Turbine Hawaii 15.9 Dropped

- in Alaska or in Hawaii

Keahole 8083 21 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Keahole 8083 22 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Keahole 8083 23 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Keahole 8083 7 Combined Cycle Hawaii 16 Dropped

- in Alaska or in Hawaii

Keahole 8083 CT4 Combined Cycle Hawaii 19.8 Dropped

- in Alaska or in Hawaii

Keahole 8083 CT5 Combined Cycle Hawaii 19.8 Dropped

- in Alaska or in Hawaii

Hendricks Regional Health 54731 GE06 Combustion Turbine Indiana 1 Dropped

- Onsite Unit

Hendricks Regional Health 54731 GEO1 Combustion Turbine Indiana 0.5 Dropped

- Onsite Unit

Hendricks Regional Health 54731 GEO2 Combustion Turbine Indiana 0.5 Dropped

- Onsite Unit

Hendricks Regional Health 54731 GEO3 Combustion Turbine Indiana 0.3 Dropped

- Onsite Unit

## 124 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Hendricks Regional Health 54731 GEO4 Combustion Turbine Indiana 1 Dropped

- Onsite Unit

Hendricks Regional Health 54731 GEO5 Combustion Turbine Indiana 1 Dropped

- Onsite Unit

Hercules Brunswick Plant 10120 GEN5 Biomass Georgia 7.1 Dropped

- Onsite Unit

Hercules Brunswick Plant 10120 GEN6 Biomass Georgia 2 Dropped

- Onsite Unit

CSL Behring LLC 54790 GEN1 Combustion Turbine Illinois 3.8 Dropped

- Onsite Unit

Hofstra University 51035 GEN1 Combustion Turbine New York 1.1 Dropped

- Onsite Unit

Hofstra University 51035 GEN2 Combustion Turbine New York 1.1 Dropped

- Onsite Unit

Aventis Pharmaceuticals 10122 2 Combustion Turbine New Jersey 4 Dropped

- Onsite Unit

Hoge Lumber 10739 AC3M Biomass Ohio 1.2 Dropped

- Onsite Unit

Hoge Lumber 10739 W750 Biomass Ohio 0.3 Dropped

- Onsite Unit

Hoffmann LaRoche 10123 TG01 Combustion Turbine New Jersey 4.1 Dropped

- Onsite Unit

Hoffmann LaRoche 10123 TG03 Combustion Turbine New Jersey 4.1 Dropped

- Onsite Unit

Hoffer Plastics 54523 GEN1 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Hoffer Plastics 54523 GEN2 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Hoffer Plastics 54523 GEN3 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Hoffer Plastics 54523 GEN4 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Hoffer Plastics 54523 GEN5 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Hoffer Plastics 54523 GEN6 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Hoffer Plastics 54523 GEN7 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Hoffer Plastics 54523 GEN8 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Hoffer Plastics 54523 GEN9 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Center Falls 10853 1 Hydro New York 0.3 Dropped

- Onsite Unit

Center Falls 10853 2 Hydro New York 0.3 Dropped

- Onsite Unit

Center Falls 10853 3 Hydro New York 0.2 Dropped

- Onsite Unit

Honeywell Farms 10125 1 Combustion Turbine New York 0.8 Dropped

- Onsite Unit

Honeywell Farms 10125 2 Combustion Turbine New York 0.8 Dropped

- Onsite Unit

Honeywell Farms 10125 3 Combustion Turbine New York 0.8 Dropped

- Onsite Unit

Honeywell Farms 10125 4 Combustion Turbine New York 0.8 Dropped

- Onsite Unit

Honeywell Farms 10125 5 Combustion Turbine New York 0.8 Dropped

- Onsite Unit

Honeywell Farms 10125 6 Combustion Turbine New York 0.4 Dropped

- Onsite Unit

## 125 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Riverside 1607 4 Hydro Massachusetts 0.8 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Riverside 1607 5 Hydro Massachusetts 0.6 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Cabot Holyoke 9864 6 O/G Steam Massachusetts 9.3 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Cabot Holyoke 9864 8 O/G Steam Massachusetts 9.3 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Harris Energy Realty 54981 ALBA Hydro Massachusetts 0.3 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Harris Energy Realty 54981 ALBD Hydro Massachusetts 0.4 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Harris Energy Realty 54981 C

- AB Hydro Massachusetts 0.3 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Harris Energy Realty 54981 C

- C Hydro Massachusetts 0.2 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Harris Energy Realty 54981 GILA Hydro Massachusetts 0.5 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Harris Energy Realty 54981 GILD Hydro Massachusetts 0.3 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Harris Energy Realty 54981 NONO Hydro Massachusetts 0.5 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Harris Energy Realty 54981 TOM Hydro Massachusetts 0.4 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Hopkinton 8108 IC2 Combustion Turbine Iowa 1.7 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Hopkinton 8108 IC3 Combustion Turbine Iowa 1.2 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Hugoton 1 1289 6 Combustion Turbine Kansas 1.2 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Hutzel Hospital 10232 TB

- 1 Combustion Turbine Michigan 0.7 Dropped

- Onsite Unit

Hutzel Hospital 10232 TB

- 2 Combustion Turbine Michigan 0.7 Dropped

- Onsite Unit

Hutchinson Plant #1 1980 5 Combustion Turbine Minnesota 1.7 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Hutchinson Plant #1 1980 6 Combustion Turbine Minnesota 1.7 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Hutchinson Plant #1 1980 7 Combustion Turbine Minnesota 4.5 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

New Halen 7183 1 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

New Halen 7183 2 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

New Halen 7183 3 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

New Halen 7183 4 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

International Paper Riegelwood Mill 54656 NO 1 Non

- Fossil Waste North Carolina 7.8 Dropped

- Onsite Unit

International Paper Riegelwood Mill 54656 NO 2 Non

- Fossil Waste North Carolina 8.3 Dropped

- Onsite Unit

International Paper Riegelwood Mill 54656 NO3 Non

- Fossil Waste North Carolina 44.5 Dropped

- Onsite Unit

Ingersoll Milling Machine 50989 71 Combustion Turbine Illinois 0.6 Dropped

- Onsite Unit

Ingersoll Milling Machine 50989 72 Combustion Turbine Illinois 0.6 Dropped

- Onsite Unit

Ingersoll Milling Machine 50989 73 Combustion Turbine Illinois 0.6 Dropped

- Onsite Unit

## 126 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Ingersoll Milling Machine 50989 74 Combustion Turbine Illinois 0.6 Dropped

- Onsite Unit

Ingersoll Milling Machine 50989 75 Combustion Turbine Illinois 0.6 Dropped

- Onsite Unit

Ingersoll Milling Machine 50989 76 Combustion Turbine Illinois 0.7 Dropped

- Onsite Unit

Ingersoll Milling Machine 50989 77 Combustion Turbine Illinois 0.7 Dropped

- Onsite Unit

Mansfield Mill 54091 GEN1 Non

- Fossil Waste Louisiana 24.6 Dropped

- Onsite Unit

Mansfield Mill 54091 GEN2 Non

- Fossil Waste Louisiana 25.6 Dropped

- Onsite Unit

Mansfield Mill 54091 GEN3 Non

- Fossil Waste Louisiana 22.1 Dropped

- Onsite Unit

Mansfield Mill 54091 GEN4 Combustion Turbine Louisiana 14.8 Dropped

- Onsite Unit

Indian River Generating Station 594 3 Coal Steam Delaware 170 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

International Paper Franklin Mill 52152 GE10 Combustion Turbine Virginia 38 Dropped

- Onsite Unit

International Paper Franklin Mill 52152 GEN1 Non

- Fossil Waste Virginia 5 Dropped

- Onsite Unit

International Paper Franklin Mill 52152 GEN2 Non

- Fossil Waste Virginia 3.7 Dropped

- Onsite Unit

International Paper Franklin Mill 52152 GEN3 Non

- Fossil Waste Virginia 2.5 Dropped

- Onsite Unit

International Paper Franklin Mill 52152 GEN6 Non

- Fossil Waste Virginia 9.3 Dropped

- Onsite Unit

International Paper Franklin Mill 52152 GEN7 Non

- Fossil Waste Virginia 15.6 Dropped

- Onsite Unit

International Paper Franklin Mill 52152 GEN8 Non

- Fossil Waste Virginia 27.5 Dropped

- Onsite Unit

International Paper Franklin Mill 52152 GEN9 Non

- Fossil Waste Virginia 36.1 Dropped

- Onsite Unit

Ticonderoga Mill 54099 GEN1 O/G Steam New York 41 Dropped

- Onsite Unit

International Paper Augusta Mill 54358 1 Non

- Fossil Waste Georgia 25.3 Dropped

- Onsite Unit

International Paper Augusta Mill 54358 2 Non

- Fossil Waste Georgia 36.5 Dropped

- Onsite Unit

International Paper Augusta Mill 54358 3 Non

- Fossil Waste Georgia 17.5 Dropped

- Onsite Unit

International Paper Vicksburg Mill 54100 GEN1 Non

- Fossil Waste Mississippi 1.5 Dropped

- Onsite Unit

International Paper Vicksburg Mill 54100 GEN2 Non

- Fossil Waste Mississippi 37 Dropped

- Onsite Unit

International Paper Courtland Mill 50245 ABB Non

- Fossil Waste Alabama 62 Dropped

- Onsite Unit

International Paper Courtland Mill 50245 GE Non

- Fossil Waste Alabama 27 Dropped

- Onsite Unit

International Paper Courtland Mill 50245 GT Combustion Turbine Alabama 30 Dropped

- Onsite Unit

International Paper Texarkana Mill 54097 GEN1 Non

- Fossil Waste Texas 25 Dropped

- Onsite Unit

International Paper Texarkana Mill 54097 GEN2 Non

- Fossil Waste Texas 40 Dropped

- Onsite Unit

International Paper Georgetown Mill 54087 GEN1 Non

- Fossil Waste South Carolina 23.8 Dropped

- Onsite Unit

International Paper Georgetown Mill 54087 GEN2 Biomass South Carolina 27.4 Dropped

- Onsite Unit

## 127 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

International Paper Georgetown Mill 54087 GEN3 Biomass South Carolina 37.7 Dropped

- Onsite Unit

International Paper Riverdale Mill 54096 GEN1 O/G Steam Alabama 7 Dropped

- Onsite Unit

International Paper Riverdale Mill 54096 GEN2 O/G Steam Alabama 31 Dropped

- Onsite Unit

International Paper Riverdale Mill 54096 GEN3 Combined Cycle Alabama 5 Dropped

- Onsite Unit

International Paper Riverdale Mill 54096 GEN4 Combined Cycle Alabama 32 Dropped

- Onsite Unit

Interstate Paper LLC Riceboro 54281 577A Non

- Fossil Waste Georgia 13 Dropped

- Onsite Unit

International Paper Pensacola 50250 GEN1 Non

- Fossil Waste Florida 36 Dropped

- Onsite Unit

International Paper Pensacola 50250 GEN2 Non

- Fossil Waste Florida 40 Dropped

- Onsite Unit

Iowa Methodist Medical Center 10655 1 Combustion Turbine Iowa 1.5 Dropped

- Onsite Unit

Iowa Methodist Medical Center 10655 2 Combustion Turbine Iowa 1.5 Dropped

- Onsite Unit

Iowa Methodist Medical Center 10655 3 Combustion Turbine Iowa 0.5 Dropped

- Onsite Unit

Dubuque 1046 3 Coal Steam Iowa 31.6 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Dubuque 1046 4 Coal Steam Iowa 36.3 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Fox Lake 1888 1 O/G Steam Minnesota 12.7 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

International Paper Eastover Facility 52151 GEN1 Non

- Fossil Waste South Carolina 46 Dropped

- Onsite Unit

International Paper Eastover Facility 52151 GEN2 Non

- Fossil Waste South Carolina 57 Dropped

- Onsite Unit

Iowa State University 54201 GEN3 Coal Steam Iowa 13.3 Dropped

- Onsite Unit

Iowa State University 54201 GEN4 Coal Steam Iowa 6.3 Dropped

- Onsite Unit

Iowa State University 54201 GEN5 Coal Steam Iowa 11.5 Dropped

- Onsite Unit

Iowa State University 54201 GEN6 Coal Steam Iowa 15.1 Dropped

- Onsite Unit

Arcelormittal Cleveland Inc 10398 GEN3 Fossil Waste Ohio 10 Dropped

- Onsite Unit

Arcelormittal Cleveland Inc 10398 GEN5 Fossil Waste Ohio 10 Dropped

- Onsite Unit

Arcelormittal Cleveland Inc 10398 GENA Fossil Waste Ohio 15 Dropped

- Onsite Unit

Arcelormittal Cleveland Inc 10398 GENB Fossil Waste Ohio 10 Dropped

- Onsite Unit

Arcelormittal Cleveland Inc 10398 GENC Fossil Waste Ohio 23 Dropped

- Onsite Unit

IVEX Packaging 52032 1 Combustion Turbine Illinois 3.5 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Jefferson Smurfit Fernandina Beach 10202 GEN5 Biomass Florida 30 Dropped

- Onsite Unit

Jefferson Smurfit Fernandina Beach 10202 GEN6 Coal Steam Florida 50 Dropped

- Onsite Unit

John Deere Dubuque Works 54414 GE10 Combustion Turbine Iowa 1.4 Dropped

- Onsite Unit

John Deere Dubuque Works 54414 GEN5 Combustion Turbine Iowa 1.4 Dropped

- Onsite Unit

## 128 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

John Deere Dubuque Works 54414 GEN6 Combustion Turbine Iowa 1.4 Dropped

- Onsite Unit

John Deere Dubuque Works 54414 GEN7 Combustion Turbine Iowa 1.4 Dropped

- Onsite Unit

John Deere Dubuque Works 54414 GEN8 Combustion Turbine Iowa 1.4 Dropped

- Onsite Unit

John Deere Dubuque Works 54414 GEN9 Combustion Turbine Iowa 1.4 Dropped

- Onsite Unit

John Deere Harvester Works 10039 GEN2 Coal Steam Illinois 2 Dropped

- Onsite Unit

John Deere Harvester Works 10039 GEN4 Coal Steam Illinois 2.5 Dropped

- Onsite Unit

John Deere Harvester Works 10039 GEN5 Coal Steam Illinois 3 Dropped

- Onsite Unit

John Deere Harvester Works 10039 GEN6 Coal Steam Illinois 2.5 Dropped

- Onsite Unit

King Cove 7493 1 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

King Cove 7493 2 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

King Cove 7493 3 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

King Cove 7493 4 Hydro Alaska 0.7 Dropped

- in Alaska or in Hawaii

King Cove 7493 5 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Kalaeola Cogen Plant 54646 CT1 Combined Cycle Hawaii 82 Dropped

- in Alaska or in Hawaii

Kalaeola Cogen Plant 54646 CT2 Combined Cycle Hawaii 82 Dropped

- in Alaska or in Hawaii

Kalaeola Cogen Plant 54646 ST Combined Cycle Hawaii 50 Dropped

- in Alaska or in Hawaii

Port Allen 6474 3 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Port Allen 6474 4 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Port Allen 6474 5 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Port Allen 6474 8 Combustion Turbine Hawaii 7.6 Dropped

- in Alaska or in Hawaii

Port Allen 6474 9 Combustion Turbine Hawaii 7.6 Dropped

- in Alaska or in Hawaii

Port Allen 6474 D6 Combustion Turbine Hawaii 7.6 Dropped

- in Alaska or in Hawaii

Port Allen 6474 D7 Combustion Turbine Hawaii 7.6 Dropped

- in Alaska or in Hawaii

Port Allen 6474 GT1 Combined Cycle Hawaii 17.5 Dropped

- in Alaska or in Hawaii

Port Allen 6474 GT2 Combined Cycle Hawaii 22.6 Dropped

- in Alaska or in Hawaii

Port Allen 6474 IC1 Combustion Turbine Hawaii 1.7 Dropped

- in Alaska or in Hawaii

Port Allen 6474 IC2 Combustion Turbine Hawaii 1.7 Dropped

- in Alaska or in Hawaii

Port Allen 6474 ST1 Combined Cycle Hawaii 9 Dropped

- in Alaska or in Hawaii

Kapaia Power Station 56258 CT1 Combustion Turbine Hawaii 26.6 Dropped

- in Alaska or in Hawaii

Kaweah Delta District Hospital 10042 KDHT1 Combustion Turbine California 3.5 Dropped

- Onsite Unit

## 129 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Swan Lake 70 1 Hydro Alaska 11.2 Dropped

- in Alaska or in Hawaii

Swan Lake 70 2 Hydro Alaska 11.2 Dropped

- in Alaska or in Hawaii

Ketchikan 84 3 Hydro Alaska 1.4 Dropped

- in Alaska or in Hawaii

Ketchikan 84 4 Hydro Alaska 1.4 Dropped

- in Alaska or in Hawaii

Ketchikan 84 5 Hydro Alaska 1.4 Dropped

- in Alaska or in Hawaii

S W Bailey 85 1 Combustion Turbine Alaska 3.5 Dropped

- in Alaska or in Hawaii

S W Bailey 85 2 Combustion Turbine Alaska 3.5 Dropped

- in Alaska or in Hawaii

S W Bailey 85 3 Combustion Turbine Alaska 5.5 Dropped

- in Alaska or in Hawaii

S W Bailey 85 4 Combustion Turbine Alaska 10.5 Dropped

- in Alaska or in Hawaii

Beaver Falls 6580 1 Hydro Alaska 1 Dropped

- in Alaska or in Hawaii

Beaver Falls 6580 3 Hydro Alaska 2.2 Dropped

- in Alaska or in Hawaii

Beaver Falls 6580 4 Hydro Alaska 2.2 Dropped

- in Alaska or in Hawaii

Silvis 6581 1 Hydro Alaska 2.1 Dropped

- in Alaska or in Hawaii

Klein Tools Chicago 10498 17 Combustion Turbine Illinois 1.5 Dropped

- Onsite Unit

Koppers Chicago Plant 10732 GEN1 Fossil Waste Illinois 5 Dropped

- Onsite Unit

Terror Lake 71 1 Hydro Alaska 11.2 Dropped

- in Alaska or in Hawaii

Terror Lake 71 2 Hydro Alaska 11.2 Dropped

- in Alaska or in Hawaii

Kodiak 6281 1 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Kodiak 6281 2c Combustion Turbine Alaska 4.4 Dropped

- in Alaska or in Hawaii

Kodiak 6281 3c Combustion Turbine Alaska 4.4 Dropped

- in Alaska or in Hawaii

Kodiak 6281 4 Combustion Turbine Alaska 7 Dropped

- in Alaska or in Hawaii

Kodiak 6281 6A Combustion Turbine Alaska 2 Dropped

- in Alaska or in Hawaii

Kodiak 6281 7A Combustion Turbine Alaska 2 Dropped

- in Alaska or in Hawaii

Port Lions 6282 1 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Port Lions 6282 2 Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Port Lions 6282 3 Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Port Lions 6282 4 Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Nymans Plant 7723 1 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Nymans Plant 7723 2 Combustion Turbine Alaska 7.3 Dropped

- in Alaska or in Hawaii

Pillar Mountain Wind Project 57187 1 Wind Alaska 4.5 Dropped

- in Alaska or in Hawaii

## 130 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Kotzebue 6304 10 Combustion Turbine Alaska 3 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 10wt Wind Alaska 0.1 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 11 Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 11wt Wind Alaska 0.1 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 12 Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 12wt Wind Alaska 0.1 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 13WT Wind Alaska 0.1 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 14 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 14wt Wind Alaska 0.1 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 15 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 15WT Wind Alaska 0.1 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 16WT Wind Alaska 0.1 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 17WT Wind Alaska 0.1 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 1WT Wind Alaska 0.6 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 2WT Wind Alaska 0.1 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 3WT Wind Alaska 0.2 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 4WT Wind Alaska 0.5 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 5WT Wind Alaska 0.1 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 6WT Wind Alaska 0.1 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 7A Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 7WT Wind Alaska 0.3 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 8WT Wind Alaska 0.1 Dropped

- in Alaska or in Hawaii

Kotzebue 6304 9wt Wind Alaska 0.1 Dropped

- in Alaska or in Hawaii

Lagoon Cogeneration Facility 50942 1 Combustion Turbine Utah 0.5 Dropped

- Onsite Unit

Lagoon Cogeneration Facility 50942 2 Combustion Turbine Utah 0.5 Dropped

- Onsite Unit

Lagoon Cogeneration Facility 50942 3 Combustion Turbine Utah 0.5 Dropped

- Onsite Unit

Lavalley Lumber LLC 50914 1500 Biomass Maine 1.2 Dropped

- Onsite Unit

Lavalley Lumber LLC 50914 350 Combustion Turbine Maine 0.3 Dropped

- Onsite Unit

Lederle Laboratories 10521 3A Combined Cycle New York 1.5 Dropped

- Onsite Unit

Lederle Laboratories 10521 GEN1 Combined Cycle New York 8.3 Dropped

- Onsite Unit

## 131 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Lederle Laboratories 10521 GEN2 Combined Cycle New York 8.3 Dropped

- Onsite Unit

Lederle Laboratories 10521 GEN3 Combined Cycle New York 2.2 Dropped

- Onsite Unit

Lederle Laboratories 10521 TG4 Combined Cycle New York 2 Dropped

- Onsite Unit

Leviton Manufacturing 55637 GEN1 Combustion Turbine Texas 1.8 Dropped

- Onsite Unit

Fourche Creek Wastewater 10050 3 Non

- Fossil Waste Arkansas 0.5 Dropped

- Onsite Unit

Fourche Creek Wastewater 10050 4 Non

- Fossil Waste Arkansas 1.3 Dropped

- Onsite Unit

Hoover Company 55536 542 Combustion Turbine Texas 1.8 Dropped

- Onsite Unit

Hoover Company 55536 543 Combustion Turbine Texas 1.8 Dropped

- Onsite Unit

Hoover Company 55536 544 Combustion Turbine Texas 1.8 Dropped

- Onsite Unit

Hoover Company 55536 545 Combustion Turbine Texas 1.8 Dropped

- Onsite Unit

Loma Linda University Cogen 10206 GEN1 Combined Cycle California 4.8 Dropped

- Onsite Unit

Loma Linda University Cogen 10206 GEN2 Combined Cycle California 4.8 Dropped

- Onsite Unit

Loma Linda University Cogen 10206 GEN3 Combined Cycle California 1.2 Dropped

- Onsite Unit

Loma Linda University Cogen 10206 GEN4 Combustion Turbine California 1.7 Dropped

- Onsite Unit

Longview Fibre 54562 4 Non

- Fossil Waste Washington 10 Dropped

- Onsite Unit

Longview Fibre 54562 6 Non

- Fossil Waste Washington 22 Dropped

- Onsite Unit

Longview Fibre 54562 7 Non

- Fossil Waste Washington 25 Dropped

- Onsite Unit

Longview Fibre 54562 8 Combustion Turbine Washington 60 Dropped

- Onsite Unit

Total Energy Facilities 10091 G2 Non

- Fossil Waste California 8 Dropped

- Onsite Unit

Total Energy Facilities 10091 G3 Non

- Fossil Waste California 8 Dropped

- Onsite Unit

Total Energy Facilities 10091 GEN1 Non

- Fossil Waste California 8 Dropped

- Onsite Unit

Total Energy Facilities 10091 GEN4 Fossil Waste California 4.7 Dropped

- Onsite Unit

Louisiana Tech University Power Plant 54240 TG3 Combustion Turbine Louisiana 6.4 Dropped

- Onsite Unit

Lowell 1837 5 Combustion Turbine Michigan 1.1 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Lowell 1837 6 Combustion Turbine Michigan 1.1 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Lowell 1837 7 Combustion Turbine Michigan 1.4 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

South Georgia Medical Center 54848 GEN 7 Combustion Turbine Georgia 0.8 Dropped

- Onsite Unit

South Georgia Medical Center 54848 GEN1 Combustion Turbine Georgia 0.4 Dropped

- Onsite Unit

South Georgia Medical Center 54848 GEN2 Combustion Turbine Georgia 0.4 Dropped

- Onsite Unit

South Georgia Medical Center 54848 GEN3 Combustion Turbine Georgia 0.4 Dropped

- Onsite Unit

## 132 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

South Georgia Medical Center 54848 GEN4 Combustion Turbine Georgia 0.7 Dropped

- Onsite Unit

Lutheran Medical Center 54769 GEN1 Combustion Turbine New York 0.8 Dropped

- Onsite Unit

Lutheran Medical Center 54769 GEN2 Combustion Turbine New York 0.8 Dropped

- Onsite Unit

Mars Snackfood US 54855 1 Combustion Turbine Illinois 3 Dropped

- Onsite Unit

M C Dixon Lumber 54745 GEN1 Biomass Alabama 2.1 Dropped

- Onsite Unit

MARS Chocolate North American LLC 10061 GEN1 Combined Cycle New Jersey 10 Dropped

- Onsite Unit

MARS Chocolate North American LLC 10061 GEN2 Combined Cycle New Jersey 0.7 Dropped

- Onsite Unit

M A Patout Son Ltd 51008 1000 Biomass Louisiana 1 Dropped

- Onsite Unit

M A Patout Son Ltd 51008 2000 Biomass Louisiana 2 Dropped

- Onsite Unit

Deer Island Treatment Plant 10823 G101 Combustion Turbine Massachusetts 22 Dropped

- Onsite Unit

Deer Island Treatment Plant 10823 G201 Combustion Turbine Massachusetts 22 Dropped

- Onsite Unit

Deer Island Treatment Plant 10823 H101 Hydro Massachusetts 1 Dropped

- Onsite Unit

Deer Island Treatment Plant 10823 H201 Hydro Massachusetts 1 Dropped

- Onsite Unit

Deer Island Treatment Plant 10823 PV101 Solar PV Massachusetts 0.1 Dropped

- Onsite Unit

Deer Island Treatment Plant 10823 S101 Non

- Fossil Waste Massachusetts 9 Dropped

- Onsite Unit

Deer Island Treatment Plant 10823 WT101 Wind Massachusetts 0.6 Dropped

- Onsite Unit

Deer Island Treatment Plant 10823 WT102 Wind Massachusetts 0.6 Dropped

- Onsite Unit

Anson Abenaki Hydros 10186 AB1 Hydro Maine 2.2 Dropped

- Onsite Unit

Anson Abenaki Hydros 10186 AB2 Hydro Maine 2.2 Dropped

- Onsite Unit

Anson Abenaki Hydros 10186 AB3 Hydro Maine 2.2 Dropped

- Onsite Unit

Anson Abenaki Hydros 10186 AB4 Hydro Maine 2.2 Dropped

- Onsite Unit

Anson Abenaki Hydros 10186 AB5 Hydro Maine 2.2 Dropped

- Onsite Unit

Anson Abenaki Hydros 10186 AB6 Hydro Maine 2.6 Dropped

- Onsite Unit

Anson Abenaki Hydros 10186 AB7 Hydro Maine 2.2 Dropped

- Onsite Unit

Anson Abenaki Hydros 10186 AB8 Hydro Maine 0.3 Dropped

- Onsite Unit

Anson Abenaki Hydros 10186 AN1 Hydro Maine 1.8 Dropped

- Onsite Unit

Anson Abenaki Hydros 10186 AN2 Hydro Maine 1.8 Dropped

- Onsite Unit

Anson Abenaki Hydros 10186 AN3 Hydro Maine 1.8 Dropped

- Onsite Unit

Anson Abenaki Hydros 10186 AN4 Hydro Maine 1.8 Dropped

- Onsite Unit

Anson Abenaki Hydros 10186 AN5 Hydro Maine 1.8 Dropped

- Onsite Unit

## 133 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Anson Abenaki Hydros 10186 STG1 O/G Steam Maine 2 Dropped

- Onsite Unit

Blount Street 3992 3 Coal Steam Wisconsin 39.4 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Blount Street 3992 4 Coal Steam Wisconsin 21.2 Dropped

- PLANNED_RETIREMENT_YEAR < =2015

Blount Street 3992 5 Coal Steam Wisconsin 26.6 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Marathon Electric 50990 P1

- 1 Combustion Turbine Wisconsin 0.4 Dropped

- Onsite Unit

Marathon Electric 50990 P1

- 2 Combustion Turbine Wisconsin 0.4 Dropped

- Onsite Unit

Marathon Electric 50990 P2

- 3 Combustion Turbine Wisconsin 0.9 Dropped

- Onsite Unit

Marathon Electric 50990 P2

- 4 Combustion Turbine Wisconsin 0.9 Dropped

- Onsite Unit

Martinez Refining 54912 GTG1 Combined Cycle California 36 Dropped

- Onsite Unit

Martinez Refining 54912 GTG2 Combined Cycle California 36 Dropped

- Onsite Unit

Martinez Refining 54912 STG1 Combined Cycle California 18 Dropped

- Onsite Unit

Eastern Correctional Institute 10693 1147 Biomass Maryland 1.3 Dropped

- Onsite Unit

Eastern Correctional Institute 10693 1148 Biomass Maryland 1.3 Dropped

- Onsite Unit

Eastern Correctional Institute 10693 DG1 Combustion Turbine Maryland 1 Dropped

- Onsite Unit

Eastern Correctional Institute 10693 DG2 Combustion Turbine Maryland 1 Dropped

- Onsite Unit

Mass Inst Tech Cntrl Utilities/Cogen Plt 54907 CTG1 Combustion Turbine Massachusetts 19 Dropped

- Onsite Unit

Unalakleet 6299 5 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Unalakleet 6299 6 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Unalakleet 6299 7 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Unalakleet 6299 8 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Palaau Power 792 15 Combustion Turbine Hawaii 2 Dropped

- in Alaska or in Hawaii

Palaau Power 792 7 Combustion Turbine Hawaii 2.1 Dropped

- in Alaska or in Hawaii

Palaau Power 792 8 Combustion Turbine Hawaii 2.1 Dropped

- in Alaska or in Hawaii

Palaau Power 792 9 Combustion Turbine Hawaii 2.1 Dropped

- in Alaska or in Hawaii

Palaau Power 792 CAT1 Combustion Turbine Hawaii 1.2 Dropped

- in Alaska or in Hawaii

Palaau Power 792 CAT2 Combustion Turbine Hawaii 1.2 Dropped

- in Alaska or in Hawaii

Palaau Power 792 CUM3 Combustion Turbine Hawaii 0.9 Dropped

- in Alaska or in Hawaii

Palaau Power 792 CUM4 Combustion Turbine Hawaii 0.9 Dropped

- in Alaska or in Hawaii

Palaau Power 792 CUM5 Combustion Turbine Hawaii 0.9 Dropped

- in Alaska or in Hawaii

Palaau Power 792 CUM6 Combustion Turbine Hawaii 0.9 Dropped

- in Alaska or in Hawaii

## 134 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Kahului 6056 1 O/G Steam Hawaii 4.7 Dropped

- in Alaska or in Hawaii

Kahului 6056 2 O/G Steam Hawaii 4.7 Dropped

- in Alaska or in Hawaii

Kahului 6056 3 O/G Steam Hawaii 11 Dropped

- in Alaska or in Hawaii

Kahului 6056 4 O/G Steam Hawaii 11.9 Dropped

- in Alaska or in Hawaii

Maalaea 6504 1 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Maalaea 6504 10 Combustion Turbine Hawaii 12 Dropped

- in Alaska or in Hawaii

Maalaea 6504 11 Combustion Turbine Hawaii 12 Dropped

- in Alaska or in Hawaii

Maalaea 6504 12 Combustion Turbine Hawaii 12 Dropped

- in Alaska or in Hawaii

Maalaea 6504 13 Combustion Turbine Hawaii 12 Dropped

- in Alaska or in Hawaii

Maalaea 6504 14 Combined Cycle Hawaii 20 Dropped

- in Alaska or in Hawaii

Maalaea 6504 15 Combined Cycle Hawaii 15 Dropped

- in Alaska or in Hawaii

Maalaea 6504 16 Combined Cycle Hawaii 20 Dropped

- in Alaska or in Hawaii

Maalaea 6504 17 Combined Cycle Hawaii 21.2 Dropped

- in Alaska or in Hawaii

Maalaea 6504 18 Combined Cycle Hawaii 15 Dropped

- in Alaska or in Hawaii

Maalaea 6504 19 Combined Cycle Hawaii 21.2 Dropped

- in Alaska or in Hawaii

Maalaea 6504 2 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Maalaea 6504 3 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Maalaea 6504 4 Combustion Turbine Hawaii 5.3 Dropped

- in Alaska or in Hawaii

Maalaea 6504 5 Combustion Turbine Hawaii 5.3 Dropped

- in Alaska or in Hawaii

Maalaea 6504 6 Combustion Turbine Hawaii 5.4 Dropped

- in Alaska or in Hawaii

Maalaea 6504 7 Combustion Turbine Hawaii 5.4 Dropped

- in Alaska or in Hawaii

Maalaea 6504 8 Combustion Turbine Hawaii 5.3 Dropped

- in Alaska or in Hawaii

Maalaea 6504 9 Combustion Turbine Hawaii 5.4 Dropped

- in Alaska or in Hawaii

Maalaea 6504 X1 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Maalaea 6504 X2 Combustion Turbine Hawaii 2.5 Dropped

- in Alaska or in Hawaii

Miki Basin 7264 LL1 Combustion Turbine Hawaii 1 Dropped

- in Alaska or in Hawaii

Miki Basin 7264 LL2 Combustion Turbine Hawaii 1 Dropped

- in Alaska or in Hawaii

Miki Basin 7264 LL3 Combustion Turbine Hawaii 1 Dropped

- in Alaska or in Hawaii

Miki Basin 7264 LL4 Combustion Turbine Hawaii 1 Dropped

- in Alaska or in Hawaii

Miki Basin 7264 LL5 Combustion Turbine Hawaii 1 Dropped

- in Alaska or in Hawaii

## 135 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Miki Basin 7264 LL6 Combustion Turbine Hawaii 1 Dropped

- in Alaska or in Hawaii

Miki Basin 7264 LL7 Combustion Turbine Hawaii 2.1 Dropped

- in Alaska or in Hawaii

Miki Basin 7264 LL8 Combustion Turbine Hawaii 2.1 Dropped

- in Alaska or in Hawaii

Hana Substation 56055 MH1 Combustion Turbine Hawaii 1 Dropped

- in Alaska or in Hawaii

Hana Substation 56055 MH2 Combustion Turbine Hawaii 1 Dropped

- in Alaska or in Hawaii

Kalaheo Hydro 10412 KAL Hydro Hawaii 1.1 Dropped

- in Alaska or in Hawaii

Wainiha Hydro 10413 WAIA Hydro Hawaii 1.7 Dropped

- in Alaska or in Hawaii

Wainiha Hydro 10413 WAIB Hydro Hawaii 1.7 Dropped

- in Alaska or in Hawaii

McGrath 6555 6 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

McGrath 6555 7 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

Monterey Regional Water Cogen Facility 54951 EG1 Non

- Fossil Waste California 0.5 Dropped

- Onsite Unit

Monterey Regional Water Cogen Facility 54951 EG2 Non

- Fossil Waste California 0.5 Dropped

- Onsite Unit

Monterey Regional Water Cogen Facility 54951 EG3 Non

- Fossil Waste California 0.5 Dropped

- Onsite Unit

Mead Coated Board 54802 GEN1 Biomass Alabama 32 Dropped

- Onsite Unit

Mead Coated Board 54802 GEN2 Biomass Alabama 55.5 Dropped

- Onsite Unit

Mead Coated Board 54802 GEN3 Combustion Turbine Alabama 21 Dropped

- Onsite Unit

West Point 52149 COG3 Combustion Turbine Pennsylvania 38.5 Dropped

- Onsite Unit

West Point 52149 GEN1 O/G Steam Pennsylvania 3 Dropped

- Onsite Unit

West Point 52149 GEN2 Combustion Turbine Pennsylvania 24.5 Dropped

- Onsite Unit

West Point 52149 GEN3 Combustion Turbine Pennsylvania 2.4 Dropped

- Onsite Unit

West Point 52149 GEN4 Combustion Turbine Pennsylvania 1.7 Dropped

- Onsite Unit

West Point 52149 GEN5 Combustion Turbine Pennsylvania 1.2 Dropped

- Onsite Unit

West Point 52149 GEN6 Combustion Turbine Pennsylvania 1.2 Dropped

- Onsite Unit

West Point 52149 GEN7 Combustion Turbine Pennsylvania 0.7 Dropped

- Onsite Unit

West Point 52149 GEN8 Combustion Turbine Pennsylvania 1 Dropped

- Onsite Unit

West Point 52149 GEN9 Combustion Turbine Pennsylvania 0.9 Dropped

- Onsite Unit

West Point 52149 GN10 Combustion Turbine Pennsylvania 0.9 Dropped

- Onsite Unit

West Point 52149 GN11 Combustion Turbine Pennsylvania 0.9 Dropped

- Onsite Unit

MeadWestvaco Evadale 50101 GEN1 Non

- Fossil Waste Texas 7.5 Dropped

- Onsite Unit

MeadWestvaco Evadale 50101 GEN2 Non

- Fossil Waste Texas 32.6 Dropped

- Onsite Unit

## 136 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

MeadWestvaco Evadale 50101 GEN3 Non

- Fossil Waste Texas 17.6 Dropped

- Onsite Unit

Merck Rahway Power Plant 10224 GEN8 O/G Steam New Jersey 4.8 Dropped

- Onsite Unit

Merck Rahway Power Plant 10224 GEN9 O/G Steam New Jersey 10 Dropped

- Onsite Unit

Elkton 52148 GEN1 O/G Steam Virginia 2 Dropped

- Onsite Unit

Elkton 52148 GEN2 Combustion Turbine Virginia 0.8 Dropped

- Onsite Unit

Metropolitan Sewerage District 10181 GEN1 Hydro North Carolina 0.8 Dropped

- Onsite Unit

Metropolitan Sewerage District 10181 GEN2 Hydro North Carolina 0.8 Dropped

- Onsite Unit

Metropolitan Sewerage District 10181 GEN3 Hydro North Carolina 0.8 Dropped

- Onsite Unit

Purple Lake 6302 1 Hydro Alaska 1.3 Dropped

- in Alaska or in Hawaii

Purple Lake 6302 2 Hydro Alaska 1.3 Dropped

- in Alaska or in Hawaii

Purple Lake 6302 3 Hydro Alaska 1.3 Dropped

- in Alaska or in Hawaii

Centennial 7112 IC6 Combustion Turbine Alaska 3.3 Dropped

- in Alaska or in Hawaii

Chester Lake 7168 1 Hydro Alaska 1 Dropped

- in Alaska or in Hawaii

Central District Wastewater Treat Plant 54623 1 Non

- Fossil Waste Florida 1.2 Dropped

- Onsite Unit

Central District Wastewater Treat Plant 54623 2 Non

- Fossil Waste Florida 1.2 Dropped

- Onsite Unit

Central District Wastewater Treat Plant 54623 3 Non

- Fossil Waste Florida 1.2 Dropped

- Onsite Unit

Central District Wastewater Treat Plant 54623 4 Non

- Fossil Waste Florida 1.2 Dropped

- Onsite Unit

South District Wastewater Treatment Plt 54624 1 Non

- Fossil Waste Florida 0.9 Dropped

- Onsite Unit

South District Wastewater Treatment Plt 54624 2 Non

- Fossil Waste Florida 0.9 Dropped

- Onsite Unit

South District Wastewater Treatment Plt 54624 3 Non

- Fossil Waste Florida 0.9 Dropped

- Onsite Unit

Potomac River 3788 1 Coal Steam Virginia 88 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Potomac River 3788 2 Coal Steam Virginia 88 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Potomac River 3788 3 Coal Steam Virginia 102 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Potomac River 3788 4 Coal Steam Virginia 102 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Potomac River 3788 5 Coal Steam Virginia 102 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

MMSD Jones Island Wastewater 54851 GEN1 Combustion Turbine Wisconsin 13 Dropped

- Onsite Unit

MMSD Jones Island Wastewater 54851 GEN2 Combustion Turbine Wisconsin 13 Dropped

- Onsite Unit

MMSD South Shore Wastewater 55525 1 Non

- Fossil Waste Wisconsin 1.4 Dropped

- Onsite Unit

MMSD South Shore Wastewater 55525 1CAT Non

- Fossil Waste Wisconsin 0.9 Dropped

- Onsite Unit

MMSD South Shore Wastewater 55525 2CAT Non

- Fossil Waste Wisconsin 0.9 Dropped

- Onsite Unit

## 137 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

MMSD South Shore Wastewater 55525 3CAT Non

- Fossil Waste Wisconsin 0.9 Dropped

- Onsite Unit

MMSD South Shore Wastewater 55525 4CAT Non

- Fossil Waste Wisconsin 0.9 Dropped

- Onsite Unit

Potrero Power 273 3 O/G Steam California 206 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Potrero Power 273 4 Combustion Turbine California 52 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Potrero Power 273 5 Combustion Turbine California 52 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Potrero Power 273 6 Combustion Turbine California 52 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Contra Costa 228 6 O/G Steam California 335 Dropped

- PLANNED_RETIREMENT_YEAR < =2015

Contra Costa 228 7 O/G Steam California 337 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Mills Pride 54978 2058 Biomass Ohio 0.5 Dropped

- Onsite Unit

Mills Pride 54978 2076 Biomass Ohio 0.5 Dropped

- Onsite Unit

Eaton 2046 1 O/G Steam Mississippi 24.5 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Eaton 2046 2 O/G Steam Mississippi 24.5 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Eaton 2046 3 O/G Steam Mississippi 24.6 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Mississippi Baptist Medical Center 54203 A Combustion Turbine Mississippi 4 Dropped

- Onsite Unit

ExxonMobil Oil Torrance Refinery 50624 EXP1 Coal Steam California 7.5 Dropped

- Onsite Unit

ExxonMobil Oil Torrance Refinery 50624 GTG1 Combustion Turbine California 22.5 Dropped

- Onsite Unit

ExxonMobil Oil Torrance Refinery 50624 STG1 Non

- Fossil Waste California 19.3 Dropped

- Onsite Unit

Montclair Cogen Facility 54708 1 Combustion Turbine New Jersey 3.7 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Motiva Enterprises Port Arthur Refinery 50973 GN26 Combined Cycle Texas 9.7 Dropped

- Onsite Unit

Motiva Enterprises Port Arthur Refinery 50973 GN27 O/G Steam Texas 4.3 Dropped

- Onsite Unit

Motiva Enterprises Port Arthur Refinery 50973 GN31 O/G Steam Texas 5.9 Dropped

- Onsite Unit

Motiva Enterprises Port Arthur Refinery 50973 GN32 O/G Steam Texas 15 Dropped

- Onsite Unit

Motiva Enterprises Port Arthur Refinery 50973 GN33 O/G Steam Texas 8 Dropped

- Onsite Unit

Motiva Enterprises Port Arthur Refinery 50973 GN34 Combined Cycle Texas 15.6 Dropped

- Onsite Unit

Motiva Enterprises Port Arthur Refinery 50973 GN35 Combined Cycle Texas 22.5 Dropped

- Onsite Unit

Morton Salt Rittman 54335 GEN1 Coal Steam Ohio 1.5 Dropped

- Onsite Unit

Mosinee Paper 50614 GEN1 Non

- Fossil Waste Wisconsin 13 Dropped

- Onsite Unit

Mosinee Paper 50614 HYD1 Hydro Wisconsin 2 Dropped

- Onsite Unit

Mosinee Paper 50614 HYD2 Hydro Wisconsin 0.7 Dropped

- Onsite Unit

Mosinee Paper 50614 HYD3 Hydro Wisconsin 0.7 Dropped

- Onsite Unit

## 138 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Mosinee Paper 50614 WEST Non

- Fossil Waste Wisconsin 5 Dropped

- Onsite Unit

Murphy

- Brown LLC 55002 1 Combustion Turbine North Carolina 1.2 Dropped

- Onsite Unit

Murphy

- Brown LLC 55002 2 Combustion Turbine North Carolina 1.2 Dropped

- Onsite Unit

Papillion Creek Wastewater 55027 951 Non

- Fossil Waste Nebraska 0.5 Dropped

- Onsite Unit

Papillion Creek Wastewater 55027 952 Non

- Fossil Waste Nebraska 0.5 Dropped

- Onsite Unit

Papillion Creek Wastewater 55027 953 Non

- Fossil Waste Nebraska 0.5 Dropped

- Onsite Unit

Missouri River Wastewater Treatment 55033 6013 Non

- Fossil Waste Nebraska 1 Dropped

- Onsite Unit

Missouri River Wastewater Treatment 55033 6101 Non

- Fossil Waste Nebraska 1 Dropped

- Onsite Unit

Missouri River Wastewater Treatment 55033 6102 Non

- Fossil Waste Nebraska 1 Dropped

- Onsite Unit

Naknek 6301 4A Combustion Turbine Alaska 1.3 Dropped

- in Alaska or in Hawaii

Naknek 6301 5A Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Naknek 6301 6A Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Naknek 6301 7A Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Naknek 6301 8 Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Naknek 6301 NA1 Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Naknek 6301 NA2 Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Naknek 6301 NA3 Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

Naknek 6301 NA4 Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

Naknek 6301 NA5 Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

New York University Central Plant 54808 D2 Combustion Turbine New York 0.6 Dropped

- Onsite Unit

New York University Central Plant 54808 D3 Combustion Turbine New York 0.6 Dropped

- Onsite Unit

New York University Central Plant 54808 D4 Combustion Turbine New York 0.6 Dropped

- Onsite Unit

New York University Central Plant 54808 D5 Combustion Turbine New York 0.6 Dropped

- Onsite Unit

New York University Central Plant 54808 D6 Combustion Turbine New York 0.6 Dropped

- Onsite Unit

New York University Central Plant 54808 D7 Combustion Turbine New York 0.6 Dropped

- Onsite Unit

New York University Central Plant 54808 DI Combustion Turbine New York 0.6 Dropped

- Onsite Unit

New York University Central Plant 54808 GT1 Combined Cycle New York 5.5 Dropped

- Onsite Unit

New York University Central Plant 54808 GT2 Combined Cycle New York 5.5 Dropped

- Onsite Unit

New York University Central Plant 54808 T1 Combined Cycle New York 1.8 Dropped

- Onsite Unit

Newman 54250 1 O/G Steam Pennsylvania 1.8 Dropped

- Onsite Unit

## 139 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Snake River 90 11 Combustion Turbine Alaska 1.5 Dropped

- in Alaska or in Hawaii

Snake River 90 12 Combustion Turbine Alaska 3.7 Dropped

- in Alaska or in Hawaii

Snake River 90 14 Combustion Turbine Alaska 1.9 Dropped

- in Alaska or in Hawaii

Snake River 90 15 Combustion Turbine Alaska 5.2 Dropped

- in Alaska or in Hawaii

Snake River 90 16 Combustion Turbine Alaska 5.2 Dropped

- in Alaska or in Hawaii

Snake River 90 9 Combustion Turbine Alaska 2.9 Dropped

- in Alaska or in Hawaii

Juniata Locomotive Shop 10302 GEN1 Coal Steam Pennsylvania 0.3 Dropped

- Onsite Unit

Juniata Locomotive Shop 10302 GEN2 Coal Steam Pennsylvania 0.3 Dropped

- Onsite Unit

Dean H Mitchell 996 9A Combustion Turbine Indiana 17 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

5 AC Station 54995 17TG Fossil Waste Indiana 75 Dropped

- Onsite Unit

Black Dog 1904 3 Coal Steam Minnesota 79 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Black Dog 1904 4 Coal Steam Minnesota 162 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Dillingham 109 10 Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Dillingham 109 11 Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Dillingham 109 12 Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Dillingham 109 13 Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Dillingham 109 14 Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Dillingham 109 15 Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Dillingham 109 16 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Wichita Plant 50169 GEN1 Combustion Turbine Kansas 27 Dropped

- Onsite Unit

Bayville Central Facility 54569 COG1 Non

- Fossil Waste New Jersey 0.3 Dropped

- Onsite Unit

Bayville Central Facility 54569 COG2 Non

- Fossil Waste New Jersey 0.3 Dropped

- Onsite Unit

Bayville Central Facility 54569 COG3 Non

- Fossil Waste New Jersey 0.3 Dropped

- Onsite Unit

Bayville Central Facility 54569 COG4 Combustion Turbine New Jersey 1.5 Dropped

- Onsite Unit

Bayville Central Facility 54569 COG5 Combustion Turbine New Jersey 1.5 Dropped

- Onsite Unit

Bayville Central Facility 54569 COG6 Combustion Turbine New Jersey 1.5 Dropped

- Onsite Unit

Bayville Central Facility 54569 COG7 Combustion Turbine New Jersey 1.5 Dropped

- Onsite Unit

Bayville Central Facility 54569 CPV1 Solar PV New Jersey 0.2 Dropped

- Onsite Unit

Oakwood Hospital & Medical Center 50260 1 2M Combustion Turbine Michigan 2 Dropped

- Onsite Unit

Oakwood Hospital & Medical Center 50260 2 2M Combustion Turbine Michigan 2 Dropped

- Onsite Unit

## 140 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Oakwood Hospital & Medical Center 50260 500A Combustion Turbine Michigan 0.5 Dropped

- Onsite Unit

Oakwood Hospital & Medical Center 50260 500KW Combustion Turbine Michigan 0.5 Dropped

- Onsite Unit

Elk Hills Cogen 55950 U1 Combustion Turbine California 23.3 Dropped

- Onsite Unit

Elk Hills Cogen 55950 U2 Combustion Turbine California 23.3 Dropped

- Onsite Unit

Oklahoma State University 54779 GEN1 O/G Steam Oklahoma 1.6 Dropped

- Onsite Unit

Oklahoma State University 54779 GEN2 O/G Steam Oklahoma 1.6 Dropped

- Onsite Unit

Oklahoma State University 54779 GEN4 O/G Steam Oklahoma 5.2 Dropped

- Onsite Unit

Plant No 1 50696 GEN1 Non

- Fossil Waste California 2.4 Dropped

- Onsite Unit

Plant No 1 50696 GEN2 Non

- Fossil Waste California 2.4 Dropped

- Onsite Unit

Plant No 1 50696 GEN3 Non

- Fossil Waste California 2.4 Dropped

- Onsite Unit

Plant No 2 52099 GEN1 Non

- Fossil Waste California 2.7 Dropped

- Onsite Unit

Plant No 2 52099 GEN2 Non

- Fossil Waste California 2.7 Dropped

- Onsite Unit

Plant No 2 52099 GEN3 Non

- Fossil Waste California 2.7 Dropped

- Onsite Unit

Plant No 2 52099 GEN4 Non

- Fossil Waste California 2.7 Dropped

- Onsite Unit

Plant No 2 52099 GEN5 Non

- Fossil Waste California 2.7 Dropped

- Onsite Unit

Plant No 2 52099 GEN6 Non

- Fossil Waste California 0.9 Dropped

- Onsite Unit

PPG Powerhouse A 50487 A1 Non

- Fossil Waste Louisiana 7.5 Dropped

- Onsite Unit

PPG Powerhouse A 50487 A2 Non

- Fossil Waste Louisiana 7.5 Dropped

- Onsite Unit

PPG Powerhouse A 50487 A4 Non

- Fossil Waste Louisiana 7.5 Dropped

- Onsite Unit

PPG Powerhouse A 50487 A7 Non

- Fossil Waste Louisiana 10 Dropped

- Onsite Unit

PPG Powerhouse A 50487 A9 Non

- Fossil Waste Louisiana 20 Dropped

- Onsite Unit

Alta Powerhouse 214 2 Hydro California 1 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Cow Creek 229 1 Hydro California 0.9 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Cow Creek 229 2 Hydro California 0.9 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Kilarc 253 1 Hydro California 1.6 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Kilarc 253 2 Hydro California 1.6 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Packaging Corp of America 50296 GEN1 Non

- Fossil Waste Tennessee 50 Dropped

- Onsite Unit

Packaging Corp of America 50296 GEN2 Non

- Fossil Waste Tennessee 22.5 Dropped

- Onsite Unit

Packaging of America Tomahawk Mill 50476 GEN1 Coal Steam Wisconsin 5.4 Dropped

- Onsite Unit

Packaging of America Tomahawk Mill 50476 GEN2 Coal Steam Wisconsin 8.2 Dropped

- Onsite Unit

## 141 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Packaging of America Tomahawk Mill 50476 GEN3 Hydro Wisconsin 0.5 Dropped

- Onsite Unit

Packaging of America Tomahawk Mill 50476 GEN4 Hydro Wisconsin 0.3 Dropped

- Onsite Unit

Packaging of America Tomahawk Mill 50476 GEN5 Hydro Wisconsin 0.3 Dropped

- Onsite Unit

Municipal Cogen Plant 50674 GEN1 Combustion Turbine California 0.6 Dropped

- Onsite Unit

Municipal Cogen Plant 50674 GEN2 Combustion Turbine California 0.6 Dropped

- Onsite Unit

Panduit Tinley Park 54932 GEN1 Combustion Turbine Illinois 0.7 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Panduit Tinley Park 54932 GEN2 Combustion Turbine Illinois 0.7 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Park 500 Philip Morris USA 50275 TG2 Coal Steam Virginia 2 Dropped

- Onsite Unit

Park 500 Philip Morris USA 50275 TG3 Coal Steam Virginia 10.5 Dropped

- Onsite Unit

Caribou Generation Station 1513 1 O/G Steam Maine 9 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Flos Inn Diesel 1514 FID1 Combustion Turbine Maine 1.4 Dropped

- Onsite Unit

Flos Inn Diesel 1514 FID2 Combustion Turbine Maine 1.4 Dropped

- Onsite Unit

Flos Inn Diesel 1514 FID3 Combustion Turbine Maine 1.4 Dropped

- Onsite Unit

Standby Generation Plant 50310 1 Combustion Turbine Florida 1.1 Dropped

- Onsite Unit

Standby Generation Plant 50310 1SB Combustion Turbine Florida 1.3 Dropped

- Onsite Unit

Standby Generation Plant 50310 2 Combustion Turbine Florida 1.1 Dropped

- Onsite Unit

Standby Generation Plant 50310 2SB Combustion Turbine Florida 1.3 Dropped

- Onsite Unit

Standby Generation Plant 50310 3 Combustion Turbine Florida 1.1 Dropped

- Onsite Unit

Standby Generation Plant 50310 3SB Combustion Turbine Florida 1.3 Dropped

- Onsite Unit

Standby Generation Plant 50310 4SB Combustion Turbine Florida 1.3 Dropped

- Onsite Unit

Standby Generation Plant 50310 5SB Combustion Turbine Florida 1.3 Dropped

- Onsite Unit

Standby Generation Plant 50310 6SB Combustion Turbine Florida 1.3 Dropped

- Onsite Unit

Standby Generation Plant 50310 7SB Combustion Turbine Florida 1.3 Dropped

- Onsite Unit

Standby Generation Plant 50310 8SB Combustion Turbine Florida 1.3 Dropped

- Onsite Unit

Oilseed Plant 10515 GEN1 Coal Steam Virginia 1.6 Dropped

- Onsite Unit

Petersburg 91 3 Hydro Alaska 1.6 Dropped

- in Alaska or in Hawaii

Petersburg 91 IC1 Combustion Turbine Alaska 1.7 Dropped

- in Alaska or in Hawaii

Petersburg 91 IC2 Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Petersburg 91 IC3 Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Petersburg 91 IC4 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

## 142 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Petersburg 91 IC5 Combustion Turbine Alaska 0.7 Dropped

- in Alaska or in Hawaii

Petersburg 91 IC6 Combustion Turbine Alaska 2.3 Dropped

- in Alaska or in Hawaii

Petersburg 91 IC7 Combustion Turbine Alaska 2.3 Dropped

- in Alaska or in Hawaii

Phelps Dodge Refining 54628 2607 Combustion Turbine Texas 2.6 Dropped

- Onsite Unit

Phelps Dodge Refining 54628 2608 Combustion Turbine Texas 2.6 Dropped

- Onsite Unit

Phelps Dodge Refining 54628 3001 Combustion Turbine Texas 3.2 Dropped

- Onsite Unit

Phelps Dodge Refining 54628 3002 Combustion Turbine Texas 3.2 Dropped

- Onsite Unit

Phelps Dodge Refining 54628 3003 Combustion Turbine Texas 3.2 Dropped

- Onsite Unit

Pfizer Groton Plant 54236 GT

- 1 Combustion Turbine Connecticut 9.5 Dropped

- Onsite Unit

Pfizer Groton Plant 54236 TG 2 O/G Steam Connecticut 2.5 Dropped

- Onsite Unit

Pfizer Groton Plant 54236 TG 3 O/G Steam Connecticut 9.4 Dropped

- Onsite Unit

Pfizer Groton Plant 54236 TG 4 O/G Steam Connecticut 10 Dropped

- Onsite Unit

Pfizer Groton Plant 54236 TG5 O/G Steam Connecticut 7.5 Dropped

- Onsite Unit

Phelps Dodge Tyrone 54734 1 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Phelps Dodge Tyrone 54734 10 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Phelps Dodge Tyrone 54734 11 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Phelps Dodge Tyrone 54734 12 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Phelps Dodge Tyrone 54734 13 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Phelps Dodge Tyrone 54734 14 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Phelps Dodge Tyrone 54734 15 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Phelps Dodge Tyrone 54734 2 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Phelps Dodge Tyrone 54734 3 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Phelps Dodge Tyrone 54734 4 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Phelps Dodge Tyrone 54734 5 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Phelps Dodge Tyrone 54734 6 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Phelps Dodge Tyrone 54734 7 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Phelps Dodge Tyrone 54734 8 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Phelps Dodge Tyrone 54734 9 Combustion Turbine New Mexico 2.9 Dropped

- Onsite Unit

Bergen Generating Station 2398 3 Combustion Turbine New Jersey 21 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

PSEG Burlington Generating Station 2399 8 Combustion Turbine New Jersey 21 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

## 143 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

PSEG Hudson Generating Station 2403 1 O/G Steam New Jersey 355 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

PSEG Kearny Generating Station 2404 10 Combustion Turbine New Jersey 122 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

PSEG Kearny Generating Station 2404 11 Combustion Turbine New Jersey 128 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

PSEG Kearny Generating Station 2404 9 Combustion Turbine New Jersey 21 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

PSEG Linden Generating Station 2406 3 Combustion Turbine New Jersey 21 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

PSEG Mercer Generating Station 2408 3 Combustion Turbine New Jersey 115 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

PSEG National Park Generating Station 2409 1 Combustion Turbine New Jersey 21 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

PSEG Sewaren Generating Station 2411 6 Combustion Turbine New Jersey 105 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Port Allen 50389 GEN1 Combustion Turbine Louisiana 2.5 Dropped

- Onsite Unit

Port Allen 50389 GEN2 Combustion Turbine Louisiana 2.7 Dropped

- Onsite Unit

PCS Nitrogen Fertilizer LP 50341 GEN2 Non

- Fossil Waste Louisiana 8 Dropped

- Onsite Unit

Benning 603 15 O/G Steam District of Columbia 275 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Benning 603 16 O/G Steam District of Columbia 275 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Point 604 E1 Combustion Turbine District of Columbia 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Point 604 E2 Combustion Turbine District of Columbia 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Point 604 E4 Combustion Turbine District of Columbia 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Point 604 E5 Combustion Turbine District of Columbia 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Point 604 E6 Combustion Turbine District of Columbia 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Point 604 E7 Combustion Turbine District of Columbia 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Point 604 E8 Combustion Turbine District of Columbia 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Point 604 W10 Combustion Turbine District of Columbia 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Point 604 W11 Combustion Turbine District of Columbia 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Point 604 W12 Combustion Turbine District of Columbia 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Point 604 W13 Combustion Turbine District of Columbia 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Point 604 W14 Combustion Turbine District of Columbia 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Point 604 W15 Combustion Turbine District of Columbia 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Point 604 W16 Combustion Turbine District of Columbia 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Buzzard Point 604 W9 Combustion Turbine District of Columbia 16 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Rainbow 2193 RAI1 Hydro Montana 4 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Rainbow 2193 RAI2 Hydro Montana 4 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

## 144 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Rainbow 2193 RAI3 Hydro Montana 4 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Rainbow 2193 RAI4 Hydro Montana 4 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Rainbow 2193 RAI5 Hydro Montana 4 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Rainbow 2193 RAI6 Hydro Montana 4 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Rainbow 2193 RAI7 Hydro Montana 6 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Rainbow 2193 RAI8 Hydro Montana 6 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Linde Wilmington 50148 GEN1 Combined Cycle California 21 Dropped

- Onsite Unit

Linde Wilmington 50148 GEN2 Combined Cycle California 6 Dropped

- Onsite Unit

Procter & Gamble Mehoopany Mill 50463 GEN1 Combustion Turbine Pennsylvania 40 Dropped

- Onsite Unit

Procter & Gamble Mehoopany Mill 50463 GEN2 O/G Steam Pennsylvania 0.9 Dropped

- Onsite Unit

Procter & Gamble Cincinnati Plant 50456 GEN1 Coal Steam Ohio 11.7 Dropped

- Onsite Unit

Bridgeport Station 568 2 O/G Steam Connecticut 130.5 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Arapahoe 465 3 Coal Steam Colorado 44 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Cherokee 469 1 Coal Steam Colorado 107 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Cherokee 469 2 Coal Steam Colorado 106 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Zuni 478 2 O/G Steam Colorado 65 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Edwardsport 1004 6 O/G Steam Indiana 40 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Edwardsport 1004 7 Coal Steam Indiana 45 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Edwardsport 1004 8 Coal Steam Indiana 75 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Las Vegas 2447 1 Combustion Turbine New Mexico 20 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

PSEG Salem Generating Station 2410 3 Combustion Turbine New Jersey 38.4 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Purdue University 50240 GEN1 Coal Steam Indiana 30.8 Dropped

- Onsite Unit

Purdue University 50240 GEN2 Coal Steam Indiana 7 Dropped

- Onsite Unit

Purdue University 50240 GEN3 Combustion Turbine Indiana 1.8 Dropped

- Onsite Unit

Rayonier Jesup Mill 10560 GEN2 Biomass Georgia 4.7 Dropped

- Onsite Unit

Rayonier Jesup Mill 10560 GEN3 Biomass Georgia 7 Dropped

- Onsite Unit

Rayonier Jesup Mill 10560 GEN4 Biomass Georgia 7 Dropped

- Onsite Unit

Rayonier Jesup Mill 10560 GEN5 Non

- Fossil Waste Georgia 27.9 Dropped

- Onsite Unit

Rayonier Jesup Mill 10560 GEN6 Non

- Fossil Waste Georgia 25.1 Dropped

- Onsite Unit

Rayonier Fernandina Mill 10562 GEN3 Biomass Florida 6.5 Dropped

- Onsite Unit

## 145 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Rayonier Fernandina Mill 10562 GEN4 Biomass Florida 21 Dropped

- Onsite Unit

NRG Energy San Diego 54337 1 Combustion Turbine California 0.8 Dropped

- Onsite Unit

NRG Energy San Diego 54337 2 Combustion Turbine California 0.8 Dropped

- Onsite Unit

Saint Mary of Nazareth Hospital 54886 GEN1 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Saint Mary of Nazareth Hospital 54886 GEN2 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Saint Mary of Nazareth Hospital 54886 GEN3 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Martinez Sulfuric Acid Regeneration Plt 52063 GEN1 Non

- Fossil Waste California 4 Dropped

- Onsite Unit

Rice University 50054 GEN1 Combustion Turbine Texas 3.1 Dropped

- Onsite Unit

Rice University 50054 GEN2 Combustion Turbine Texas 3.8 Dropped

- Onsite Unit

Rhode Island Hospital 52024 GEN2 O/G Steam Rhode Island 1.7 Dropped

- Onsite Unit

Rhode Island Hospital 52024 GEN4 O/G Steam Rhode Island 1.7 Dropped

- Onsite Unit

Rhode Island Hospital 52024 NEW1 O/G Steam Rhode Island 3 Dropped

- Onsite Unit

Rhode Island Hospital 52024 NEW3 O/G Steam Rhode Island 3 Dropped

- Onsite Unit

Riverwood International Macon Mill 54464 1 Non

- Fossil Waste Georgia 9 Dropped

- Onsite Unit

Riverwood International Macon Mill 54464 2 Non

- Fossil Waste Georgia 4.7 Dropped

- Onsite Unit

Riverwood International Macon Mill 54464 3 Non

- Fossil Waste Georgia 4.7 Dropped

- Onsite Unit

Riverwood International Macon Mill 54464 4 Non

- Fossil Waste Georgia 21.6 Dropped

- Onsite Unit

Plant 31 Paper Mill 50028 GEN2 O/G Steam Louisiana 6 Dropped

- Onsite Unit

Plant 31 Paper Mill 50028 GEN3 O/G Steam Louisiana 6 Dropped

- Onsite Unit

Plant 31 Paper Mill 50028 GEN4 O/G Steam Louisiana 6 Dropped

- Onsite Unit

Plant 31 Paper Mill 50028 GEN5 O/G Steam Louisiana 25 Dropped

- Onsite Unit

Plant 31 Paper Mill 50028 GEN6 O/G Steam Louisiana 20 Dropped

- Onsite Unit

Rio Grande Valley Sugar Growers 54338 GENA Biomass Texas 2.5 Dropped

- Onsite Unit

Rio Grande Valley Sugar Growers 54338 GENB Biomass Texas 2.5 Dropped

- Onsite Unit

Rio Grande Valley Sugar Growers 54338 GENC Biomass Texas 2.5 Dropped

- Onsite Unit

Somerset Plant 50406 GEN1 Non

- Fossil Waste Maine 50 Dropped

- Onsite Unit

Somerset Plant 50406 GEN2 Non

- Fossil Waste Maine 65 Dropped

- Onsite Unit

Robbins Lumber 50230 CAT Combustion Turbine Maine 1.8 Dropped

- Onsite Unit

Robbins Lumber 50230 WEST Biomass Maine 1.1 Dropped

- Onsite Unit

Norton Powerhouse 50041 GEN1 Coal Steam Massachusetts 2.5 Dropped

- Onsite Unit

## 146 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Norton Powerhouse 50041 GEN2 Coal Steam Massachusetts 3.1 Dropped

- Onsite Unit

Saint Francis Hospital 50952 GEN1 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Saint Francis Hospital 50952 GEN2 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Salem Street Dept 56289 1 Combustion Turbine Virginia 2 Dropped

- Onsite Unit

Saint Agnes Medical Center 54800 9911 Combustion Turbine California 2.7 Dropped

- Onsite Unit

Saint Agnes Medical Center 54800 9929 Combustion Turbine California 2.7 Dropped

- Onsite Unit

Santa Maria Cogen Plant 10733 GEN1 Combustion Turbine California 7 Dropped

- Onsite Unit

San Antonio Community Hospital 50234 2074 Combustion Turbine California 0.1 Dropped

- Onsite Unit

San Antonio Community Hospital 50234 2075 Combustion Turbine California 0.1 Dropped

- Onsite Unit

San Antonio Community Hospital 50234 2076 Combustion Turbine California 0.1 Dropped

- Onsite Unit

W B Tuttle 3613 1 O/G Steam Texas 60 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

W B Tuttle 3613 3 O/G Steam Texas 100 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

W B Tuttle 3613 4 O/G Steam Texas 154 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

San Diego State University 50061 GEN2 Combined Cycle California 4.6 Dropped

- Onsite Unit

San Diego State University 50061 GEN3 Combined Cycle California 4.6 Dropped

- Onsite Unit

San Diego State University 50061 GEN4 Combined Cycle California 4.1 Dropped

- Onsite Unit

Sappi Cloquet Mill 50639 GEN3 Biomass Minnesota 14.8 Dropped

- Onsite Unit

Sappi Cloquet Mill 50639 GEN4 Biomass Minnesota 20.5 Dropped

- Onsite Unit

Sappi Cloquet Mill 50639 GEN5 Non

- Fossil Waste Minnesota 14 Dropped

- Onsite Unit

Sappi Cloquet Mill 50639 HGN1 Hydro Minnesota 1.6 Dropped

- Onsite Unit

Sappi Cloquet Mill 50639 HGN5 Hydro Minnesota 0.5 Dropped

- Onsite Unit

Sappi Cloquet Mill 50639 HGN6 Hydro Minnesota 0.5 Dropped

- Onsite Unit

Sappi Cloquet Mill 50639 HGN7 Hydro Minnesota 1 Dropped

- Onsite Unit

SJ/SC WPCP 56080 E2 Non

- Fossil Waste California 0.8 Dropped

- Onsite Unit

SJ/SC WPCP 56080 E3 Non

- Fossil Waste California 0.8 Dropped

- Onsite Unit

SJ/SC WPCP 56080 E5 Non

- Fossil Waste California 1.8 Dropped

- Onsite Unit

SJ/SC WPCP 56080 EG1 Combustion Turbine California 2.8 Dropped

- Onsite Unit

SJ/SC WPCP 56080 EG2 Combustion Turbine California 2.8 Dropped

- Onsite Unit

SJ/SC WPCP 56080 EG3 Combustion Turbine California 2.8 Dropped

- Onsite Unit

Schering Cogen Facility 54970 GEN1 Combustion Turbine New Jersey 3.5 Dropped

- Onsite Unit

## 147 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Schering Cogen Facility 54970 GEN2 Combustion Turbine New Jersey 3.5 Dropped

- Onsite Unit

Seward 92 3 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Seward 92 4 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Seward 92 5 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Seward 92 6 Combustion Turbine Alaska 2.8 Dropped

- in Alaska or in Hawaii

Seward 92 N1 Combustion Turbine Alaska 2.8 Dropped

- in Alaska or in Hawaii

Seward 92 N2 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Simplot Phosphates 54472 GEN1 Non

- Fossil Waste Wyoming 11.5 Dropped

- Onsite Unit

Westhollow Technology Center 54330 1 Combustion Turbine Texas 3.7 Dropped

- Onsite Unit

Shepherd Center 54813 1 Combustion Turbine Georgia 0.6 Dropped

- Onsite Unit

Shepherd Center 54813 2 Combustion Turbine Georgia 0.6 Dropped

- Onsite Unit

Shepherd Center 54813 3 Combustion Turbine Georgia 0.2 Dropped

- Onsite Unit

Shepherd Center 54813 4 Combustion Turbine Georgia 0.3 Dropped

- Onsite Unit

Shepherd Center 54813 5 Combustion Turbine Georgia 0.6 Dropped

- Onsite Unit

Shepherd Center 54813 6 Combustion Turbine Georgia 0.6 Dropped

- Onsite Unit

Sherman Hospital 50909 1 Combustion Turbine Illinois 0.8 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Sherman Hospital 50909 2 Combustion Turbine Illinois 0.8 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Shell Deer Park 50304 GEN1 Non

- Fossil Waste Texas 45 Dropped

- Onsite Unit

Shell Deer Park 50304 GEN2 Non

- Fossil Waste Texas 45 Dropped

- Onsite Unit

Shell Deer Park 50304 GEN4 Fossil Waste Texas 70 Dropped

- Onsite Unit

Shell Deer Park 50304 GEN5 Fossil Waste Texas 70 Dropped

- Onsite Unit

Simplot Leasing Don Plant 50274 GEN1 Non

- Fossil Waste Idaho 14.8 Dropped

- Onsite Unit

Blue Lake 93 1 Hydro Alaska 3 Dropped

- in Alaska or in Hawaii

Blue Lake 93 2 Hydro Alaska 3 Dropped

- in Alaska or in Hawaii

Green Lake 313 1 Hydro Alaska 9.3 Dropped

- in Alaska or in Hawaii

Green Lake 313 2 Hydro Alaska 9.3 Dropped

- in Alaska or in Hawaii

Jarvis Street 6801 1 Combustion Turbine Alaska 2 Dropped

- in Alaska or in Hawaii

Jarvis Street 6801 2 Combustion Turbine Alaska 2.8 Dropped

- in Alaska or in Hawaii

Jarvis Street 6801 3 Combustion Turbine Alaska 2.8 Dropped

- in Alaska or in Hawaii

Jarvis Street 6801 4 Combustion Turbine Alaska 4 Dropped

- in Alaska or in Hawaii

## 148 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Sloss Industries Corp 50359 10 Fossil Waste Alabama 8.5 Dropped

- Onsite Unit

Sloss Industries Corp 50359 9 Fossil Waste Alabama 7.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GEN1 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GEN2 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GEN3 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GEN4 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GEN5 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GEN6 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GEN7 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GEN8 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GEN9 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GN10 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GN11 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GN12 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GN13 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GN14 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GN15 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GN16 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GN17 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GN18 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

Smithfield Packing Bladen 54823 GN19 Combustion Turbine North Carolina 1.5 Dropped

- Onsite Unit

West Point Mill 10017 GEN8 Non

- Fossil Waste Virginia 5 Dropped

- Onsite Unit

West Point Mill 10017 GEN9 Non

- Fossil Waste Virginia 10 Dropped

- Onsite Unit

West Point Mill 10017 GN10 Non

- Fossil Waste Virginia 25 Dropped

- Onsite Unit

West Point Mill 10017 GN11 Non

- Fossil Waste Virginia 15 Dropped

- Onsite Unit

West Point Mill 10017 GN12 Non

- Fossil Waste Virginia 46 Dropped

- Onsite Unit

Power Station 4 52132 GEN1 Combined Cycle Texas 69 Dropped

- Onsite Unit

Power Station 4 52132 GEN2 Combined Cycle Texas 69 Dropped

- Onsite Unit

Power Station 4 52132 GEN3 Combined Cycle Texas 34 Dropped

- Onsite Unit

Aliso Water Management Agency 10820 GEN1 Non

- Fossil Waste California 0.4 Dropped

- Onsite Unit

## 1 49 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Aliso Water Management Agency 10820 GEN2 Non

- Fossil Waste California 0.4 Dropped

- Onsite Unit

Aliso Water Management Agency 10820 GEN3 Non

- Fossil Waste California 0.4 Dropped

- Onsite Unit

Southern Minnesota Beet Sugar 54533 1 Coal Steam Minnesota 7.5 Dropped

- Onsite Unit

Mohave 2341 1 Coal Steam Nevada 790 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Mohave 2341 2 Coal Steam Nevada 790 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Dublin Mill 54004 GEN1 Coal Steam Georgia 44 Dropped

- Onsite Unit

Dublin Mill 54004 GEN2 Combustion Turbine Georgia 40 Dropped

- Onsite Unit

Spartanburg Water System 54675 DI1 Combustion Turbine South Carolina 1.6 Dropped

- Onsite Unit

Spartanburg Water System 54675 HG1 Hydro South Carolina 0.5 Dropped

- Onsite Unit

Spartanburg Water System 54675 HG2 Hydro South Carolina 0.5 Dropped

- Onsite Unit

Solano County Cogen Plant 50985 3163 Combustion Turbine California 1 Dropped

- Onsite Unit

Solano County Cogen Plant 50985 3164 Combustion Turbine California 0.4 Dropped

- Onsite Unit

Solano County Cogen Plant 50985 3165 Combustion Turbine California 1.4 Dropped

- Onsite Unit

Riverview 3487 6 Combustion Turbine Texas 22 Dropped

- Unit dismantled and sold per comment

CenturyLink Regional HQ 54882 GEN1 Combustion Turbine North Carolina 0.6 Dropped

- Onsite Unit

CenturyLink Regional HQ 54882 GEN2 Combustion Turbine North Carolina 0.6 Dropped

- Onsite Unit

St Josephs Hospital 54534 1 Combustion Turbine Florida 1.6 Dropped

- Onsite Unit

Saint Marys Hospital Power Plant 54262 1 Combined Cycle Minnesota 4.5 Dropped

- Onsite Unit

Saint Marys Hospital Power Plant 54262 4 Combined Cycle Minnesota 2.7 Dropped

- Onsite Unit

Saint Marys Hospital Power Plant 54262 5 Combustion Turbine Minnesota 2.5 Dropped

- Onsite Unit

Saint Marys Hospital Power Plant 54262 6 Combustion Turbine Minnesota 2.7 Dropped

- Onsite Unit

St Vincents Medical Center 54535 6805 Combustion Turbine Florida 1.3 Dropped

- Onsite Unit

Central Power Plant 50621 GEN3 O/G Steam Rhode Island 2 Dropped

- Onsite Unit

Central Power Plant 50621 GEN4 O/G Steam Rhode Island 2 Dropped

- Onsite Unit

Central Power Plant 50621 GEN5 Combustion Turbine Rhode Island 2.8 Dropped

- Onsite Unit

Central Power Plant 50621 GEN6 Combustion Turbine Rhode Island 2.8 Dropped

- Onsite Unit

State Farm Insurance Support Center East 55274 2A Combustion Turbine Georgia 1.8 Dropped

- Onsite Unit

State Farm Insurance Support Center East 55274 2B Combustion Turbine Georgia 1.8 Dropped

- Onsite Unit

State Farm Insurance Support Center East 55274 3A Combustion Turbine Georgia 1.8 Dropped

- Onsite Unit

State Farm Insurance Support Center East 55274 3B Combustion Turbine Georgia 1.8 Dropped

- Onsite Unit

## 150 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

State Farm Insurance Support Center East 55274 4A Combustion Turbine Georgia 1.8 Dropped

- Onsite Unit

State Farm Insurance Support Center East 55274 4B Combustion Turbine Georgia 1.8 Dropped

- Onsite Unit

Starrett City Cogen Facility 50743 GEN1 O/G Steam New York 5.5 Dropped

- Onsite Unit

Starrett City Cogen Facility 50743 GEN2 O/G Steam New York 5.5 Dropped

- Onsite Unit

Starrett City Cogen Facility 50743 GEN3 Combustion Turbine New York 2 Dropped

- Onsite Unit

Starrett City Cogen Facility 50743 GEN4 Combustion Turbine New York 2 Dropped

- Onsite Unit

Starrett City Cogen Facility 50743 GEN5 Combustion Turbine New York 2 Dropped

- Onsite Unit

Capitol Heat and Power 54406 1 O/G Steam Wisconsin 0.9 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Capitol Heat and Power 54406 2 O/G Steam Wisconsin 1 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

State Line Energy 981 3 Coal Steam Indiana 197 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

State Line Energy 981 3A Coal Steam Indiana Dropped

- PLANNED_RETIREMENT_YEAR <=2015

State Line Energy 981 4 Coal Steam Indiana 318 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

State Line Energy 981 4A Coal Steam Indiana Dropped

- PLANNED_RETIREMENT_YEAR <=2015

State Farm Insur Support Center Central 55390 2A Combustion Turbine Texas 1.8 Dropped

- Onsite Unit

State Farm Insur Support Center Central 55390 2B Combustion Turbine Texas 1.8 Dropped

- Onsite Unit

State Farm Insur Support Center Central 55390 3A Combustion Turbine Texas 1.8 Dropped

- Onsite Unit

State Farm Insur Support Center Central 55390 3B Combustion Turbine Texas 1.8 Dropped

- Onsite Unit

State Farm Insur Support Center Central 55390 4A Combustion Turbine Texas 1.8 Dropped

- Onsite Unit

State Farm Insur Support Center Central 55390 4B Combustion Turbine Texas 1.8 Dropped

- Onsite Unit

Smithfield Packing Wilson 56035 1 Combustion Turbine North Carolina 1.3 Dropped

- Onsite Unit

Smithfield Packing Wilson 56035 2 Combustion Turbine North Carolina 1.3 Dropped

- Onsite Unit

Stone Container Uncasville 50801 GEN1 Non

- Fossil Waste Connecticut 1.3 Dropped

- Onsite Unit

Stone Container Hodge 50810 NO 4 O/G Steam Louisiana 3 Dropped

- Onsite Unit

Stone Container Hodge 50810 NO 6 O/G Steam Louisiana 5 Dropped

- Onsite Unit

Stone Container Hodge 50810 NO 7 O/G Steam Louisiana 15.6 Dropped

- Onsite Unit

Stone Container Hodge 50810 NO 8 O/G Steam Louisiana 27.5 Dropped

- Onsite Unit

Stone Container Hodge 50810 NO 9 O/G Steam Louisiana 23.3 Dropped

- Onsite Unit

Stone Container Panama City Mill 50807 GEN3 Non

- Fossil Waste Florida 4 Dropped

- Onsite Unit

Stone Container Panama City Mill 50807 GEN4 Non

- Fossil Waste Florida 10 Dropped

- Onsite Unit

Stone Container Panama City Mill 50807 GEN6 Biomass Florida 21.8 Dropped

- Onsite Unit

## 151 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Stone Container Coshocton Mill 50811 GEN1 Biomass Ohio 12 Dropped

- Onsite Unit

Sun Trust Plaza 54845 EG

- 1 Combustion Turbine Georgia 1 Dropped

- Onsite Unit

Sun Trust Plaza 54845 EG

- 2 Combustion Turbine Georgia 1 Dropped

- Onsite Unit

Sunoco Toledo Ref Power Recovery Train 50965 GEN1 Fossil Waste Ohio 6 Dropped

- Onsite Unit

Philadelphia Refinery 52106 GEN1 Fossil Waste Pennsylvania 5.5 Dropped

- Onsite Unit

Philadelphia Refinery 52106 GEN2 Fossil Waste Pennsylvania 6.7 Dropped

- Onsite Unit

Philadelphia Refinery 52106 GEN3 Fossil Waste Pennsylvania 7.3 Dropped

- Onsite Unit

Arvah B Hopkins 688 GT1 Combustion Turbine Florida 12 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

S O Purdom 689 7 O/G Steam Florida 48 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

S O Purdom 689 GT1 Combustion Turbine Florida 10 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

S O Purdom 689 GT2 Combustion Turbine Florida 10 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

CNN Center 54323 D4_1 Combustion Turbine Georgia 1.5 Dropped

- Onsite Unit

CNN Center 54323 D4_2 Combustion Turbine Georgia 2 Dropped

- Onsite Unit

CNN Center 54323 D4_3 Combustion Turbine Georgia 2 Dropped

- Onsite Unit

CNN Center 54323 D5_1 Combustion Turbine Georgia 2 Dropped

- Onsite Unit

CNN Center 54323 D5_2 Combustion Turbine Georgia 2 Dropped

- Onsite Unit

CNN Center 54323 D5_3 Combustion Turbine Georgia 2 Dropped

- Onsite Unit

CNN Center 54323 DK2 Combustion Turbine Georgia 1.3 Dropped

- Onsite Unit

Howard F Curren Advanced Wastewater Plant 54347 1 Non

- Fossil Waste Florida 0.5 Dropped

- Onsite Unit

Howard F Curren Advanced Wastewater Plant 54347 2 Non

- Fossil Waste Florida 0.5 Dropped

- Onsite Unit

Howard F Curren Advanced Wastewater Plant 54347 3 Non

- Fossil Waste Florida 0.5 Dropped

- Onsite Unit

Howard F Curren Advanced Wastewater Plant 54347 4 Non

- Fossil Waste Florida 0.5 Dropped

- Onsite Unit

Howard F Curren Advanced Wastewater Plant 54347 5 Non

- Fossil Waste Florida 0.5 Dropped

- Onsite Unit

Tesoro Alaska Petroleum 52184 GEN1 Combustion Turbine Alaska 3.8 Dropped

- Onsite Unit

Tesoro Alaska Petroleum 52184 GEN2 Combustion Turbine Alaska 3.7 Dropped

- Onsite Unit

Widows Creek 50 1 Coal Steam Alabama 111 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Widows Creek 50 2 Coal Steam Alabama 111 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Widows Creek 50 3 Coal Steam Alabama 111 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Widows Creek 50 4 Coal Steam Alabama 111 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Widows Creek 50 5 Coal Steam Alabama 111 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

## 152 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Widows Creek 50 6 Coal Steam Alabama 111 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

John Sevier 3405 1 Coal Steam Tennessee 176 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

John Sevier 3405 2 Coal Steam Tennessee 176 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Johnsonville 3406 10 Coal Steam Tennessee 141 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Johnsonville 3406 5 Coal Steam Tennessee 107 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Johnsonville 3406 6 Coal Steam Tennessee 107 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Johnsonville 3406 7 Coal Steam Tennessee 141 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Johnsonville 3406 8 Coal Steam Tennessee 141 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Johnsonville 3406 9 Coal Steam Tennessee 141 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Mandan Refinery 52133 GEN1 Fossil Waste North Dakota 2.8 Dropped

- Onsite Unit

Mandan Refinery 52133 GEN2 Fossil Waste North Dakota 2.8 Dropped

- Onsite Unit

Mandan Refinery 52133 GEN3 Fossil Waste North Dakota 2.8 Dropped

- Onsite Unit

Tesoro Hawaii 10093 GEN1 Combustion Turbine Hawaii 20 Dropped

- in Alaska or in Hawaii

Thiele Kaolin Sandersville 54841 G1 Combustion Turbine Georgia 1.1 Dropped

- Onsite Unit

Thiele Kaolin Sandersville 54841 G2 Combustion Turbine Georgia 1.1 Dropped

- Onsite Unit

Thiele Kaolin Reedy Creek 54849 G1 Combustion Turbine Georgia 1.1 Dropped

- Onsite Unit

Thiele Kaolin Reedy Creek 54849 G2 Combustion Turbine Georgia 1.1 Dropped

- Onsite Unit

Thornwood High School 55004 1 Combustion Turbine Illinois 0.7 Dropped

- Onsite Unit

Thornwood High School 55004 2 Combustion Turbine Illinois 0.7 Dropped

- Onsite Unit

Thornridge High School 55005 1 Combustion Turbine Illinois 0.5 Dropped

- Onsite Unit

Thornridge High School 55005 2 Combustion Turbine Illinois 0.5 Dropped

- Onsite Unit

Angoon 7462 1A Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Angoon 7462 2A Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Angoon 7462 3 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Hoonah 7463 1 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

Hoonah 7463 2A Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Hoonah 7463 3 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Kake 7464 1 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

Kake 7464 2 Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Kake 7464 3A Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

## 153 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Chilkat Valley 7467 1 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

Chilkat Valley 7467 2A Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

West Group Data Center 54294 1 Combustion Turbine Minnesota 0.6 Dropped

- Onsite Unit

West Group Data Center 54294 2 Combustion Turbine Minnesota 0.6 Dropped

- Onsite Unit

West Group Data Center 54294 3 Combustion Turbine Minnesota 0.6 Dropped

- Onsite Unit

West Group Data Center 54294 4 Combustion Turbine Minnesota 0.6 Dropped

- Onsite Unit

West Group Data Center F 56247 1 Combustion Turbine Minnesota 0.6 Dropped

- Onsite Unit

West Group Data Center F 56247 2 Combustion Turbine Minnesota 0.6 Dropped

- Onsite Unit

West Group Data Center F 56247 3 Combustion Turbine Minnesota 0.6 Dropped

- Onsite Unit

West Group Data Center F 56247 4 Combustion Turbine Minnesota 0.6 Dropped

- Onsite Unit

Tuscola Station 55245 TG1 Coal Steam Illinois 3.8 Dropped

- Onsite Unit

Tuscola Station 55245 TG2 Coal Steam Illinois 4.9 Dropped

- Onsite Unit

Tuscola Station 55245 TG3 Coal Steam Illinois 4.8 Dropped

- Onsite Unit

Inner Harbor East Heating 56050 1 Combustion Turbine Maryland 2.1 Dropped

- Onsite Unit

Fort Greely Power Plant 54834 EN

- 4 Combustion Turbine Alaska 1.2 Dropped

- Onsite Unit

Fort Greely Power Plant 54834 EN

- 5 Combustion Turbine Alaska 1.2 Dropped

- Onsite Unit

Fort Greely Power Plant 54834 EN

- 6 Combustion Turbine Alaska 2.5 Dropped

- Onsite Unit

Fort Greely Power Plant 54834 EN

- 7 Combustion Turbine Alaska 2.5 Dropped

- Onsite Unit

US Gypsum Oakfield 50203 GEN1 Combustion Turbine New York 4.9 Dropped

- Onsite Unit

University of Medicine Dentistry NJ 50411 GEN1 Combustion Turbine New Jersey 3.4 Dropped

- Onsite Unit

University of Medicine Dentistry NJ 50411 GEN2 Combustion Turbine New Jersey 3.4 Dropped

- Onsite Unit

University of Medicine Dentistry NJ 50411 GEN3 Combustion Turbine New Jersey 3.4 Dropped

- Onsite Unit

Fairfield Works 50730 GEN1 Fossil Waste Alabama 20 Dropped

- Onsite Unit

Fairfield Works 50730 GEN2 Fossil Waste Alabama 20 Dropped

- Onsite Unit

Fairfield Works 50730 GEN3 Fossil Waste Alabama 20 Dropped

- Onsite Unit

Fairfield Works 50730 GEN4 Fossil Waste Alabama 20 Dropped

- Onsite Unit

Union Carbide South Charleston 50151 GEN8 Coal Steam West Virginia 5.6 Dropped

- Onsite Unit

Dutch Harbor 7502 1 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Dutch Harbor 7502 10 Combustion Turbine Alaska 4.4 Dropped

- in Alaska or in Hawaii

Dutch Harbor 7502 11 Combustion Turbine Alaska 4.4 Dropped

- in Alaska or in Hawaii

## 154 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Dutch Harbor 7502 15 Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Dutch Harbor 7502 2 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Dutch Harbor 7502 3 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Dutch Harbor 7502 4 Combustion Turbine Alaska 0.7 Dropped

- in Alaska or in Hawaii

Dutch Harbor 7502 5 Combustion Turbine Alaska 0.5 Dropped

- in Alaska or in Hawaii

Dutch Harbor 7502 6 Combustion Turbine Alaska 1.2 Dropped

- in Alaska or in Hawaii

Dutch Harbor 7502 8 Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Dutch Harbor 7502 9 Combustion Turbine Alaska 1 Dropped

- in Alaska or in Hawaii

Unalaska Power Module 7503 7 Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

University of Alaska Fairbanks 50711 GEN1 Coal Steam Alaska 0.5 Dropped

- Onsite Unit

University of Alaska Fairbanks 50711 GEN2 Coal Steam Alaska 0.5 Dropped

- Onsite Unit

University of Alaska Fairbanks 50711 GEN3 Coal Steam Alaska 8.1 Dropped

- Onsite Unit

University of Alaska Fairbanks 50711 GEN4 Combustion Turbine Alaska 9.6 Dropped

- Onsite Unit

Clairton Works 50729 GEN1 Fossil Waste Pennsylvania 16 Dropped

- Onsite Unit

Clairton Works 50729 GEN3 Fossil Waste Pennsylvania 6 Dropped

- Onsite Unit

Mon Valley Works 50732 GEN1 Fossil Waste Pennsylvania 28 Dropped

- Onsite Unit

Mon Valley Works 50732 GEN2 Fossil Waste Pennsylvania 28 Dropped

- Onsite Unit

Mon Valley Works 50732 GEN3 Fossil Waste Pennsylvania 1.9 Dropped

- Onsite Unit

Gary Works 50733 STG1 Fossil Waste Indiana 161 Dropped

- Onsite Unit

University of Illinois Cogen Facility 54044 CT1 Combustion Turbine Illinois 6.4 Dropped

- Onsite Unit

University of Illinois Cogen Facility 54044 CT2 Combustion Turbine Illinois 6.4 Dropped

- Onsite Unit

University of Illinois Cogen Facility 54044 CT3 Combustion Turbine Illinois 6.4 Dropped

- Onsite Unit

University of Illinois Cogen Facility 54044 GEN1 Combustion Turbine Illinois 6.3 Dropped

- Onsite Unit

University of Illinois Cogen Facility 54044 GEN2 Combustion Turbine Illinois 6.3 Dropped

- Onsite Unit

University of Illinois Cogen Facility 54044 GEN3 Combustion Turbine Illinois 3.7 Dropped

- Onsite Unit

University of Illinois Cogen Facility 54044 GEN4 Combustion Turbine Illinois 3.7 Dropped

- Onsite Unit

University of Illinois Cogen Facility 54044 RE1 Combustion Turbine Illinois 5.5 Dropped

- Onsite Unit

University of Illinois Cogen Facility 54044 RE2 Combustion Turbine Illinois 5.5 Dropped

- Onsite Unit

University of Illinois Cogen Facility 54044 RE3 Combustion Turbine Illinois 5.5 Dropped

- Onsite Unit

University of Illinois Abbott Power Plt 54780 T1 O/G Steam Illinois 3 Dropped

- Onsite Unit

## 155 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

University of Illinois Abbott Power Plt 54780 T10 Coal Steam Illinois 12.5 Dropped

- Onsite Unit

University of Illinois Abbott Power Plt 54780 T11 Coal Steam Illinois 12.5 Dropped

- Onsite Unit

University of Illinois Abbott Power Plt 54780 T12 Coal Steam Illinois 7 Dropped

- Onsite Unit

University of Illinois Abbott Power Plt 54780 T2 O/G Steam Illinois 3 Dropped

- Onsite Unit

University of Illinois Abbott Power Plt 54780 T3 O/G Steam Illinois 3 Dropped

- Onsite Unit

University of Illinois Abbott Power Plt 54780 T4 O/G Steam Illinois 3 Dropped

- Onsite Unit

University of Illinois Abbott Power Plt 54780 T6 Coal Steam Illinois 7.5 Dropped

- Onsite Unit

University of Illinois Abbott Power Plt 54780 T7 Coal Steam Illinois 7.5 Dropped

- Onsite Unit

University of Illinois Abbott Power Plt 54780 T8 Combustion Turbine Illinois 13 Dropped

- Onsite Unit

University of Illinois Abbott Power Plt 54780 T9 Combustion Turbine Illinois 13 Dropped

- Onsite Unit

University of Oklahoma 50307 GEN1 O/G Steam Oklahoma 7.5 Dropped

- Onsite Unit

University of Oklahoma 50307 GEN2 O/G Steam Oklahoma 2.5 Dropped

- Onsite Unit

University of Oklahoma 50307 GEN3 O/G Steam Oklahoma 2.5 Dropped

- Onsite Unit

University of Oklahoma 50307 GEN4 O/G Steam Oklahoma 4.3 Dropped

- Onsite Unit

University of Oklahoma 50307 GEN5 Combustion Turbine Oklahoma 1.8 Dropped

- Onsite Unit

Hal C Weaver Power Plant 50118 GEN10 Combined Cycle Texas 33 Dropped

- Onsite Unit

Hal C Weaver Power Plant 50118 GEN4 Combined Cycle Texas 7.6 Dropped

- Onsite Unit

Hal C Weaver Power Plant 50118 GEN5 Combined Cycle Texas 6 Dropped

- Onsite Unit

Hal C Weaver Power Plant 50118 GEN7 Combined Cycle Texas 27.6 Dropped

- Onsite Unit

Hal C Weaver Power Plant 50118 GEN8 Combined Cycle Texas 46.5 Dropped

- Onsite Unit

Hal C Weaver Power Plant 50118 GEN9 Combined Cycle Texas 26.1 Dropped

- Onsite Unit

Univ of NC Chapel Hill Cogen Facility 54276 TG3 Coal Steam North Carolina 28.7 Dropped

- Onsite Unit

Honolulu 764 H8 O/G Steam Hawaii 48.6 Dropped

- in Alaska or in Hawaii

Honolulu 764 H9 O/G Steam Hawaii 51.7 Dropped

- in Alaska or in Hawaii

Kahe 765 K1 O/G Steam Hawaii 77.9 Dropped

- in Alaska or in Hawaii

Kahe 765 K2 O/G Steam Hawaii 78.1 Dropped

- in Alaska or in Hawaii

Kahe 765 K3 O/G Steam Hawaii 82.1 Dropped

- in Alaska or in Hawaii

Kahe 765 K4 O/G Steam Hawaii 87.2 Dropped

- in Alaska or in Hawaii

Kahe 765 K5 O/G Steam Hawaii 128.1 Dropped

- in Alaska or in Hawaii

Kahe 765 K6 O/G Steam Hawaii 128.7 Dropped

- in Alaska or in Hawaii

## 156 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Waiau 766 W10 Combustion Turbine Hawaii 51.2 Dropped

- in Alaska or in Hawaii

Waiau 766 W3 O/G Steam Hawaii 47.2 Dropped

- in Alaska or in Hawaii

Waiau 766 W4 O/G Steam Hawaii 47.7 Dropped

- in Alaska or in Hawaii

Waiau 766 W5 O/G Steam Hawaii 51.9 Dropped

- in Alaska or in Hawaii

Waiau 766 W6 O/G Steam Hawaii 51.8 Dropped

- in Alaska or in Hawaii

Waiau 766 W7 O/G Steam Hawaii 77.8 Dropped

- in Alaska or in Hawaii

Waiau 766 W8 O/G Steam Hawaii 77.8 Dropped

- in Alaska or in Hawaii

Waiau 766 W9 Combustion Turbine Hawaii 51.2 Dropped

- in Alaska or in Hawaii

Campbell Industrial Park 56329 CIP1 Biomass Hawaii 113 Dropped

- in Alaska or in Hawaii

Unisea G 2 54422 CAT1 Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

Unisea G 2 54422 CAT2 Combustion Turbine Alaska 0.9 Dropped

- in Alaska or in Hawaii

Unisea G 2 54422 GEN1 Combustion Turbine Alaska 2.2 Dropped

- in Alaska or in Hawaii

Unisea G 2 54422 GEN2 Combustion Turbine Alaska 2.3 Dropped

- in Alaska or in Hawaii

Unisea G 2 54422 GEN3 Combustion Turbine Alaska 2.3 Dropped

- in Alaska or in Hawaii

Unisea G 2 54422 GEN4 Combustion Turbine Alaska 2.2 Dropped

- in Alaska or in Hawaii

Unisea G 2 54422 GEN5 Combustion Turbine Alaska 2.3 Dropped

- in Alaska or in Hawaii

Unisea G 2 54422 GEN6 Combustion Turbine Alaska 2.2 Dropped

- in Alaska or in Hawaii

Seldovia 6283 5 Combustion Turbine Alaska 1.2 Dropped

- in Alaska or in Hawaii

Seldovia 6283 6 Combustion Turbine Alaska 1.2 Dropped

- in Alaska or in Hawaii

Bradley Lake 7367 1 Hydro Alaska 63 Dropped

- in Alaska or in Hawaii

Bradley Lake 7367 2 Hydro Alaska 63 Dropped

- in Alaska or in Hawaii

Nikiski Co

- Generation 55966 GT1 Combustion Turbine Alaska 37.9 Dropped

- in Alaska or in Hawaii

University of Washington Power Plant 54809 DG3 Combustion Turbine Washington 2 Dropped

- Onsite Unit

University of Washington Power Plant 54809 DG4 Combustion Turbine Washington 2 Dropped

- Onsite Unit

University of Washington Power Plant 54809 DG5 Combustion Turbine Washington 2 Dropped

- Onsite Unit

University of Washington Power Plant 54809 DG6 Combustion Turbine Washington 2 Dropped

- Onsite Unit

University of Washington Power Plant 54809 DG7 Combustion Turbine Washington 2 Dropped

- Onsite Unit

University of Washington Power Plant 54809 TG2 O/G Steam Washington 1 Dropped

- Onsite Unit

Valero Refinery Cogeneration Unit 1 55851 GT 1 Combustion Turbine California 45.4 Dropped

- Onsite Unit

Valero Refinery Corpus Christi East 10203 GEN1 Combustion Turbine Texas 17 Dropped

- Onsite Unit

## 157 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Valero Refinery Corpus Christi East 10203 GEN2 Combustion Turbine Texas 17 Dropped

- Onsite Unit

Valero Refinery Corpus Christi West 50121 PRU Non

- Fossil Waste Texas 12 Dropped

- Onsite Unit

Valero Refinery Corpus Christi West 50121 TG1 Fossil Waste Texas 26.6 Dropped

- Onsite Unit

Valero Refinery Corpus Christi West 50121 TG2 Fossil Waste Texas 26.6 Dropped

- Onsite Unit

Paulsboro Refinery 50628 GEN1 Combined Cycle New Jersey 20.2 Dropped

- Onsite Unit

Paulsboro Refinery 50628 GEN2 Fossil Waste New Jersey 11.7 Dropped

- Onsite Unit

Paulsboro Refinery 50628 GEN3 Fossil Waste New Jersey 11.7 Dropped

- Onsite Unit

Vanderbilt University Power Plant 52048 GEN1 Coal Steam Tennessee 6.5 Dropped

- Onsite Unit

Vanderbilt University Power Plant 52048 GEN2 Coal Steam Tennessee 4.5 Dropped

- Onsite Unit

Vanderbilt University Power Plant 52048 GT1 Combustion Turbine Tennessee 4 Dropped

- Onsite Unit

Vanderbilt University Power Plant 52048 GT2 Combustion Turbine Tennessee 4 Dropped

- Onsite Unit

Valdosta Water Treatment Plant 54839 GEN1 Combustion Turbine Georgia 1.7 Dropped

- Onsite Unit

Valdosta Water Treatment Plant 54839 GEN2 Combustion Turbine Georgia 1.7 Dropped

- Onsite Unit

Warm Springs Forest Products 50426 GEN1 Biomass Oregon 2.6 Dropped

- Onsite Unit

Warm Springs Forest Products 50426 GEN2 Biomass Oregon 2.6 Dropped

- Onsite Unit

Warm Springs Forest Products 50426 GEN3 Biomass Oregon 2.6 Dropped

- Onsite Unit

Wells Manufacturing Dura Bar Division 54540 1A Combustion Turbine Illinois 0.9 Dropped

- Onsite Unit

Wells Manufacturing Dura Bar Division 54540 1B Combustion Turbine Illinois 0.9 Dropped

- Onsite Unit

Wells Manufacturing Dura Bar Division 54540 2A Combustion Turbine Illinois 0.9 Dropped

- Onsite Unit

Wells Manufacturing Dura Bar Division 54540 2B Combustion Turbine Illinois 0.9 Dropped

- Onsite Unit

Wells Manufacturing Dura Bar Division 54540 3A Combustion Turbine Illinois 0.9 Dropped

- Onsite Unit

Wells Manufacturing Dura Bar Division 54540 3B Combustion Turbine Illinois 0.9 Dropped

- Onsite Unit

Wellesley College Central Utility Plant 54937 1118 Combustion Turbine Massachusetts 1.2 Dropped

- Onsite Unit

Wellesley College Central Utility Plant 54937 1119 Combustion Turbine Massachusetts 1.2 Dropped

- Onsite Unit

Wellesley College Central Utility Plant 54937 1120 Combustion Turbine Massachusetts 1.2 Dropped

- Onsite Unit

Wellesley College Central Utility Plant 54937 1121 Combustion Turbine Massachusetts 1.3 Dropped

- Onsite Unit

Wellesley College Central Utility Plant 54937 8187 Combustion Turbine Massachusetts 1.9 Dropped

- Onsite Unit

Covington Facility 50900 GEN1 Coal Steam Virginia 10.5 Dropped

- Onsite Unit

Covington Facility 50900 GEN2 Coal Steam Virginia 10.5 Dropped

- Onsite Unit

Covington Facility 50900 GEN3 Coal Steam Virginia 10.5 Dropped

- Onsite Unit

## 158 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Covington Facility 50900 GEN4 Coal Steam Virginia 32.5 Dropped

- Onsite Unit

Covington Facility 50900 GEN5 Coal Steam Virginia 32.5 Dropped

- Onsite Unit

Weyerhaeuser New Bern NC 50188 TG1 Non

- Fossil Waste North Carolina 29.7 Dropped

- Onsite Unit

Westward Seafoods 54305 2 Combustion Turbine Alaska 2.2 Dropped

- Onsite Unit

Westward Seafoods 54305 3 Combustion Turbine Alaska 2.2 Dropped

- Onsite Unit

Westward Seafoods 54305 4 Combustion Turbine Alaska 2.2 Dropped

- Onsite Unit

Flint River Operations 50465 GEN1 Non

- Fossil Waste Georgia 42 Dropped

- Onsite Unit

Weyerhaeuser Cosmopolis 50185 TG1 Biomass Washington 8.5 Dropped

- Onsite Unit

Weyerhaeuser Cosmopolis 50185 TG2 Biomass Washington 8.5 Dropped

- Onsite Unit

Weyerhaeuser Longview WA 50187 TG1 Non

- Fossil Waste Washington 4.7 Dropped

- Onsite Unit

Weyerhaeuser Longview WA 50187 TG2 Non

- Fossil Waste Washington 4.7 Dropped

- Onsite Unit

Weyerhaeuser Longview WA 50187 TG4 Non

- Fossil Waste Washington 18 Dropped

- Onsite Unit

Weyerhaeuser Longview WA 50187 TG5 Biomass Washington 29.2 Dropped

- Onsite Unit

Suwannee River Chemical Complex 50473 SRC Non

- Fossil Waste Florida 27.3 Dropped

- Onsite Unit

Swift Creek Chemical Complex 50474 SCC Non

- Fossil Waste Florida 15.9 Dropped

- Onsite Unit

William Beaumont Hospital 50937 GENA Combustion Turbine Michigan 1.9 Dropped

- Onsite Unit

William Beaumont Hospital 50937 GENB Combustion Turbine Michigan 1.9 Dropped

- Onsite Unit

University of Texas at San Antonio 54606 GEN1 Combustion Turbine Texas 3.3 Dropped

- Onsite Unit

Wrangell 95 11 Combustion Turbine Alaska 2 Dropped

- in Alaska or in Hawaii

Wrangell 95 12 Combustion Turbine Alaska 2 Dropped

- in Alaska or in Hawaii

Wrangell 95 13 Combustion Turbine Alaska 2 Dropped

- in Alaska or in Hawaii

Wrangell 95 9 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

YKK USA Chestney 54566 BWP1 Combustion Turbine Georgia 0.5 Dropped

- Onsite Unit

YKK USA Chestney 54566 GEN1 Combustion Turbine Georgia 1.5 Dropped

- Onsite Unit

YKK USA Chestney 54566 GEN2 Combustion Turbine Georgia 1.5 Dropped

- Onsite Unit

YKK USA Chestney 54566 GEN3 Combustion Turbine Georgia 1.7 Dropped

- Onsite Unit

YKK USA Chestney 54566 SLD1 Combustion Turbine Georgia 0.5 Dropped

- Onsite Unit

University of Northern Iowa 50088 GEN1 Coal Steam Iowa 7.5 Dropped

- Onsite Unit

191 Peachtree Tower 54818 GEN1 Combustion Turbine Georgia 1.2 Dropped

- Onsite Unit

191 Peachtree Tower 54818 GEN2 Combustion Turbine Georgia 1.2 Dropped

- Onsite Unit

## 159 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

University of Tennessee Steam Plant 55036 GEN1 Combustion Turbine Tennessee 3.7 Dropped

- Onsite Unit

Pratt & Whitney 54605 FT

- 8 Combustion Turbine Connecticut 27 Dropped

- Onsite Unit

University of Texas at Dallas 54607 GEN1 Combustion Turbine Texas 3.5 Dropped

- Onsite Unit

Mooseheart Power House 50337 GEN1 Combustion Turbine Illinois 0.5 Dropped

- Onsite Unit

Mooseheart Power House 50337 GEN2 Combustion Turbine Illinois 0.5 Dropped

- Onsite Unit

Mooseheart Power House 50337 GEN3 Combustion Turbine Illinois 0.3 Dropped

- Onsite Unit

Mooseheart Power House 50337 GEN4 Combustion Turbine Illinois 0.5 Dropped

- Onsite Unit

Ford Utilities Center 50906 3 Combustion Turbine New Mexico 6 Dropped

- Onsite Unit

New Mexico State University 54975 1 Combustion Turbine New Mexico 4.5 Dropped

- Onsite Unit

Southwestern Bell Telephone 54858 E/G1 Combustion Turbine Missouri 2 Dropped

- Onsite Unit

Southwestern Bell Telephone 54858 E/G2 Combustion Turbine Missouri 2 Dropped

- Onsite Unit

Southwestern Bell Telephone 54858 E/G3 Combustion Turbine Missouri 2 Dropped

- Onsite Unit

Southwestern Bell Telephone 54858 E/G4 Combustion Turbine Missouri 2.8 Dropped

- Onsite Unit

Southwestern Bell Telephone 54858 E/G5 Combustion Turbine Missouri 2.8 Dropped

- Onsite Unit

Grimes Way 56016 1 Combustion Turbine Washington 1 Dropped

- Onsite Unit

Grimes Way 56016 2 Combustion Turbine Washington 1 Dropped

- Onsite Unit

Grimes Way 56016 3 Combustion Turbine Washington 1.7 Dropped

- Onsite Unit

Oxnard Wastewater Treatment Plant 50224 7610 Non

- Fossil Waste California 0.4 Dropped

- Onsite Unit

Oxnard Wastewater Treatment Plant 50224 7710 Non

- Fossil Waste California 0.4 Dropped

- Onsite Unit

Oxnard Wastewater Treatment Plant 50224 7810 Non

- Fossil Waste California 0.4 Dropped

- Onsite Unit

Riverside Manufacturing 54856 1753 Combustion Turbine Georgia 0.9 Dropped

- Onsite Unit

Univ of Calif Santa Cruz Cogeneration 50064 1 Combustion Turbine California 2.6 Dropped

- Onsite Unit

Southwest Texas State University 50263 GEN1 Combustion Turbine Texas 6 Dropped

- Onsite Unit

PCS Phosphate 50509 GEN1 Non

- Fossil Waste North Carolina 50 Dropped

- Onsite Unit

Eielson AFB Central Heat & Power Plant 50392 DG01 Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Eielson AFB Central Heat & Power Plant 50392 DG02 Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Eielson AFB Central Heat & Power Plant 50392 DG03 Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Eielson AFB Central Heat & Power Plant 50392 DG04 Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Eielson AFB Central Heat & Power Plant 50392 DG1 Combustion Turbine Alaska 1.8 Dropped

- in Alaska or in Hawaii

Eielson AFB Central Heat & Power Plant 50392 TG1 Coal Steam Alaska 0.5 Dropped

- in Alaska or in Hawaii

## 160 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Eielson AFB Central Heat & Power Plant 50392 TG2 Coal Steam Alaska 0.5 Dropped

- in Alaska or in Hawaii

Eielson AFB Central Heat & Power Plant 50392 TG3 Coal Steam Alaska 5 Dropped

- in Alaska or in Hawaii

Eielson AFB Central Heat & Power Plant 50392 TG4 Coal Steam Alaska 5 Dropped

- in Alaska or in Hawaii

Eielson AFB Central Heat & Power Plant 50392 TG5 Coal Steam Alaska 9 Dropped

- in Alaska or in Hawaii

Radford Army Ammunition Plant 52072 GEN1 Coal Steam Virginia 5.6 Dropped

- Onsite Unit

Radford Army Ammunition Plant 52072 GEN2 Coal Steam Virginia 5.6 Dropped

- Onsite Unit

Radford Army Ammunition Plant 52072 GEN3 Coal Steam Virginia 5.6 Dropped

- Onsite Unit

Radford Army Ammunition Plant 52072 GEN4 Coal Steam Virginia 5.6 Dropped

- Onsite Unit

Point Comfort Operations 52069 GEN1 O/G Steam Texas 14.9 Dropped

- Onsite Unit

Point Comfort Operations 52069 GEN2 O/G Steam Texas 14.9 Dropped

- Onsite Unit

Point Comfort Operations 52069 GEN3 O/G Steam Texas 14.9 Dropped

- Onsite Unit

Point Comfort Operations 52069 GEN4 O/G Steam Texas 14 Dropped

- Onsite Unit

SDS Lumber Gorge Energy Division 50231 TG2 Biomass Washington 5 Dropped

- Onsite Unit

SDS Lumber Gorge Energy Division 50231 TG3 Biomass Washington 4.7 Dropped

- Onsite Unit

Weir Cogen Plant 50848 GT1 Combustion Turbine California 3.2 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Phelps Dodge Cobre Mining 55312 1 Combustion Turbine New Mexico 0.8 Dropped

- Onsite Unit

Phelps Dodge Cobre Mining 55312 2 Combustion Turbine New Mexico 0.8 Dropped

- Onsite Unit

Phelps Dodge Cobre Mining 55312 3 Combustion Turbine New Mexico 0.8 Dropped

- Onsite Unit

Inland Paperboard Packaging Rome 10426 GEN2 Non

- Fossil Waste Georgia 5 Dropped

- Onsite Unit

Inland Paperboard Packaging Rome 10426 GEN3 Non

- Fossil Waste Georgia 5 Dropped

- Onsite Unit

Inland Paperboard Packaging Rome 10426 GEN4 Non

- Fossil Waste Georgia 20 Dropped

- Onsite Unit

Inland Paperboard Packaging Rome 10426 GEN5 Non

- Fossil Waste Georgia 31 Dropped

- Onsite Unit

Canton North Carolina 50244 GEN8 Coal Steam North Carolina 7.5 Dropped

- Onsite Unit

Canton North Carolina 50244 GEN9 Coal Steam North Carolina 7.5 Dropped

- Onsite Unit

Canton North Carolina 50244 GN10 Coal Steam North Carolina 7.5 Dropped

- Onsite Unit

Canton North Carolina 50244 GN11 Coal Steam North Carolina 7.5 Dropped

- Onsite Unit

Canton North Carolina 50244 GN12 Coal Steam North Carolina 10 Dropped

- Onsite Unit

Canton North Carolina 50244 GN13 Coal Steam North Carolina 12.5 Dropped

- Onsite Unit

Bowater Newsprint Calhoun Operation 50956 GEN1 Non

- Fossil Waste Tennessee 19 Dropped

- Onsite Unit

Bowater Newsprint Calhoun Operation 50956 GEN2 Non

- Fossil Waste Tennessee 20 Dropped

- Onsite Unit

## 161 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Bowater Newsprint Calhoun Operation 50956 GEN3 Non

- Fossil Waste Tennessee 27 Dropped

- Onsite Unit

Univ of Massachusetts Medical Center 50087 GEN1 O/G Steam Massachusetts 1.5 Dropped

- Onsite Unit

Univ of Massachusetts Medical Center 50087 GEN2 O/G Steam Massachusetts 1.5 Dropped

- Onsite Unit

Univ of Massachusetts Medical Center 50087 GEN3 O/G Steam Massachusetts 3 Dropped

- Onsite Unit

Univ of San Francisco Cogen 50089 S

- 17 Combustion Turbine California 1.4 Dropped

- Onsite Unit

Sinclair Oil Refinery 54374 NO1 O/G Steam Wyoming 0.4 Dropped

- Onsite Unit

Sinclair Oil Refinery 54374 NO2 O/G Steam Wyoming 0.4 Dropped

- Onsite Unit

Sinclair Oil Refinery 54374 NO3 O/G Steam Wyoming 1.3 Dropped

- Onsite Unit

Sinclair Oil Refinery 54374 NO5 Combustion Turbine Wyoming 1.1 Dropped

- Onsite Unit

Amalgamated Sugar LLC Nampa 54690 2250 Coal Steam Idaho 2.2 Dropped

- Onsite Unit

Amalgamated Sugar LLC Nampa 54690 500 Coal Steam Idaho 0.5 Dropped

- Onsite Unit

Amalgamated Sugar LLC Nampa 54690 6500 Coal Steam Idaho 6 Dropped

- Onsite Unit

Menominee Acquisition 52017 ST1 Coal Steam Michigan 1.5 Dropped

- Onsite Unit

Menominee Acquisition 52017 ST2 Coal Steam Michigan 2.5 Dropped

- Onsite Unit

Aera San Ardo Cogen Facility 55184 UN

- A Combustion Turbine California 2.8 Dropped

- Onsite Unit

Aera San Ardo Cogen Facility 55184 UN

- B Combustion Turbine California 2.8 Dropped

- Onsite Unit

Kraft Foods Atlantic Gelatin 50425 GEN1 O/G Steam Massachusetts 2.5 Dropped

- Onsite Unit

Kraft Foods Atlantic Gelatin 50425 GEN2 O/G Steam Massachusetts 0.3 Dropped

- Onsite Unit

Kraft Foods Atlantic Gelatin 50425 GEN3 Combustion Turbine Massachusetts 0.3 Dropped

- Onsite Unit

CFI Plant City Phosphate Complex 50371 MI34 Non

- Fossil Waste Florida 27.9 Dropped

- Onsite Unit

NSB Atquasuk Utility 7482 NA1 Combustion Turbine Alaska 0.9 Dropped

- in Alaska or in Hawaii

NSB Atquasuk Utility 7482 NA2 Combustion Turbine Alaska 0.9 Dropped

- in Alaska or in Hawaii

NSB Atquasuk Utility 7482 NA3 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

NSB Atquasuk Utility 7482 PG2 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

NSB Atquasuk Utility 7482 PG3 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

NSB Kaktovik Utility 7483 PG1A Combustion Turbine Alaska 0.9 Dropped

- in Alaska or in Hawaii

NSB Kaktovik Utility 7483 PG2A Combustion Turbine Alaska 0.9 Dropped

- in Alaska or in Hawaii

NSB Kaktovik Utility 7483 PG3A Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

NSB Kaktovik Utility 7483 PG4A Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

NSB Nuiqsut Utility 7484 PG1A Combustion Turbine Alaska 0.9 Dropped

- in Alaska or in Hawaii

## 162 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

NSB Nuiqsut Utility 7484 PG2A Combustion Turbine Alaska 0.9 Dropped

- in Alaska or in Hawaii

NSB Nuiqsut Utility 7484 PG3A Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

NSB Nuiqsut Utility 7484 PG4A Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

NSB Nuiqsut Utility 7484 PG5A Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

NSB Nuiqsut Utility 7484 PG6A Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

NSB Point Hope Utility 7485 PG1 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

NSB Point Hope Utility 7485 PG2 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

NSB Point Hope Utility 7485 PG6 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

NSB Point Hope Utility 7485 PG7 Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

NSB Point Hope Utility 7485 PG8 Combustion Turbine Alaska 0.9 Dropped

- in Alaska or in Hawaii

NSB Point Lay Utility 7486 PG1A Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

NSB Point Lay Utility 7486 PG2A Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

NSB Point Lay Utility 7486 PG3A Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

NSB Point Lay Utility 7486 PG4A Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

NSB Point Lay Utility 7486 PG5 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

NSB Point Lay Utility 7486 PG6 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

NSB Anaktuvuk Pass 7487 1 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

NSB Anaktuvuk Pass 7487 2 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

NSB Anaktuvuk Pass 7487 3 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

NSB Anaktuvuk Pass 7487 4 Combustion Turbine Alaska 0.1 Dropped

- in Alaska or in Hawaii

NSB Anaktuvuk Pass 7487 6 Combustion Turbine Alaska 0.9 Dropped

- in Alaska or in Hawaii

NSB Anaktuvuk Pass 7487 7 Combustion Turbine Alaska 0.9 Dropped

- in Alaska or in Hawaii

NSB Wainwright Utility 7488 PG1 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

NSB Wainwright Utility 7488 PG2 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

NSB Wainwright Utility 7488 PG3 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

NSB Wainwright Utility 7488 PG4A Combustion Turbine Alaska 0.9 Dropped

- in Alaska or in Hawaii

NSB Wainwright Utility 7488 PG5 Combustion Turbine Alaska 0.9 Dropped

- in Alaska or in Hawaii

Port Townsend Paper 50544 GEN4 Non

- Fossil Waste Washington 3 Dropped

- Onsite Unit

Port Townsend Paper 50544 GEN6 Non

- Fossil Waste Washington 7.5 Dropped

- Onsite Unit

Port Townsend Paper 50544 HDRO Hydro Washington 0.3 Dropped

- Onsite Unit

## 163 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Imperial Savannah LP 50146 GENA Coal Steam Georgia 2.7 Dropped

- Onsite Unit

Imperial Savannah LP 50146 GENB Coal Steam Georgia 3 Dropped

- Onsite Unit

Imperial Savannah LP 50146 GENC Coal Steam Georgia 1 Dropped

- Onsite Unit

Imperial Savannah LP 50146 GEND Coal Steam Georgia 4.5 Dropped

- Onsite Unit

Providence Memorial Hospital 50241 9541 Combustion Turbine Texas 2.1 Dropped

- Onsite Unit

Providence Memorial Hospital 50241 9542 Combustion Turbine Texas 2.1 Dropped

- Onsite Unit

Stone Container Seminole Mill 50803 GEN3 O/G Steam Florida 13 Dropped

- Onsite Unit

Pelican 6702 HC1 Hydro Alaska 0.5 Dropped

- in Alaska or in Hawaii

Pelican 6702 HC2 Hydro Alaska 0.1 Dropped

- in Alaska or in Hawaii

Pelican 6702 IC1 Combustion Turbine Alaska 0.3 Dropped

- in Alaska or in Hawaii

Pelican 6702 IC2 Combustion Turbine Alaska 0.1 Dropped

- in Alaska or in Hawaii

Pelican 6702 IC3 Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Pelican 6702 IC4 Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Pelican 6702 IC5 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Pelican 6702 IC6 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Pelican 6702 IC7 Combustion Turbine Alaska 0.4 Dropped

- in Alaska or in Hawaii

Pelican 6702 IC8 Combustion Turbine Alaska 0.2 Dropped

- in Alaska or in Hawaii

Davenport Water Pollution Control Plant 55035 GEN1 Non

- Fossil Waste Iowa 0.8 Dropped

- Onsite Unit

Davenport Water Pollution Control Plant 55035 GEN2 Non

- Fossil Waste Iowa 0.8 Dropped

- Onsite Unit

ITT Cogen Facility 52021 GEN1 Combustion Turbine Illinois 3.5 Dropped

- Onsite Unit

ITT Cogen Facility 52021 GEN2 Combustion Turbine Illinois 3.5 Dropped

- Onsite Unit

Wasatch Energy Systems Energy Recovery 55302 1 Municipal Solid Waste Utah 1.4 Dropped

- Onsite Unit

Enterprise Products Operating 10261 GEN1 Combustion Turbine Texas 4.8 Dropped

- Onsite Unit

Enterprise Products Operating 10261 GEN2 Combustion Turbine Texas Dropped

- Onsite Unit

Enterprise Products Operating 10261 GEN3 Combustion Turbine Texas 8.7 Dropped

- Onsite Unit

Enterprise Products Operating 10261 GEN4 Combustion Turbine Texas Dropped

- Onsite Unit

Enterprise Products Operating 10261 GEN5 Combustion Turbine Texas Dropped

- Onsite Unit

Enterprise Products Operating 10261 GEN6 Combustion Turbine Texas 8.7 Dropped

- Onsite Unit

Enterprise Products Operating 10261 GEN7 Combustion Turbine Texas Dropped

- Onsite Unit

Enterprise Products Operating 10261 GEN8 Combustion Turbine Texas Dropped

- Onsite Unit

## 164 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Toca Plant 54705 EG

- 1 Combustion Turbine Louisiana 0.8 Dropped

- Onsite Unit

Toca Plant 54705 EG

- 3 Combustion Turbine Louisiana 0.8 Dropped

- Onsite Unit

Toca Plant 54705 EG

- 4 Combustion Turbine Louisiana 0.7 Dropped

- Onsite Unit

Toca Plant 54705 EG2A Combustion Turbine Louisiana 0.5 Dropped

- Onsite Unit

Neptune Gas Processing Plant 56139 NPCG Combustion Turbine Louisiana 3.1 Dropped

- Onsite Unit

International Paper Savanna Mill 50398 GE10 Non

- Fossil Waste Georgia 82.7 Dropped

- Onsite Unit

International Paper Savanna Mill 50398 GEN9 Coal Steam Georgia 71.2 Dropped

- Onsite Unit

Rock

- Tenn 54513 E

- 1 Combustion Turbine Illinois 0.7 Dropped

- Onsite Unit

Rock

- Tenn 54513 E2

- A Combustion Turbine Illinois 0.7 Dropped

- Onsite Unit

Rock

- Tenn 54513 E2

- B Combustion Turbine Illinois 0.7 Dropped

- Onsite Unit

Rock

- Tenn 54513 E3 Combustion Turbine Illinois 0.8 Dropped

- Onsite Unit

Rolls Royce 54286 63F5 Combustion Turbine Indiana 2.1 Dropped

- Onsite Unit

Rolls Royce 54286 N8OT Landfill Gas Indiana 4 Dropped

- Onsite Unit

Yakutat 6637 2B Combustion Turbine Alaska 0.8 Dropped

- in Alaska or in Hawaii

Yakutat 6637 3A Combustion Turbine Alaska 0.6 Dropped

- in Alaska or in Hawaii

Yakutat 6637 4A Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Yakutat 6637 6 Combustion Turbine Alaska 1.2 Dropped

- in Alaska or in Hawaii

Lee Creek Water Treatment Facility 54283 209 Hydro Arkansas 1.3 Dropped

- Onsite Unit

Cellu Tissue Natural Dam 54878 1 Hydro New York 0.4 Dropped

- Onsite Unit

Cellu Tissue Natural Dam 54878 2 Hydro New York 0.3 Dropped

- Onsite Unit

Cellu Tissue Natural Dam 54878 3 Hydro New York 0.3 Dropped

- Onsite Unit

Opryland USA 55037 GTO1 Combustion Turbine Tennessee 3.1 Dropped

- Onsite Unit

MU Combined Heat and Power Plant 50969 DGT1 Combustion Turbine Missouri 2 Dropped

- Onsite Unit

MU Combined Heat and Power Plant 50969 GEN1 Coal Steam Missouri 6 Dropped

- Onsite Unit

MU Combined Heat and Power Plant 50969 GEN2 Coal Steam Missouri 12.2 Dropped

- Onsite Unit

MU Combined Heat and Power Plant 50969 GEN3 Coal Steam Missouri 19.2 Dropped

- Onsite Unit

MU Combined Heat and Power Plant 50969 GEN4 Coal Steam Missouri 13.3 Dropped

- Onsite Unit

MU Combined Heat and Power Plant 50969 GEN6 Combustion Turbine Missouri 0.5 Dropped

- Onsite Unit

MU Combined Heat and Power Plant 50969 GEN7 Combustion Turbine Missouri 1 Dropped

- Onsite Unit

MU Combined Heat and Power Plant 50969 NTG1 Combustion Turbine Missouri 11.4 Dropped

- Onsite Unit

## 165 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

MU Combined Heat and Power Plant 50969 NTG2 Combustion Turbine Missouri 11.4 Dropped

- Onsite Unit

Bridgeport Gas Processing Plant 55053 2723 Combustion Turbine Texas 0.8 Dropped

- Onsite Unit

Bridgeport Gas Processing Plant 55053 654 Combustion Turbine Texas 0.8 Dropped

- Onsite Unit

Bridgeport Gas Processing Plant 55053 655 Combustion Turbine Texas 0.8 Dropped

- Onsite Unit

Bridgeport Gas Processing Plant 55053 656 Combustion Turbine Texas 0.8 Dropped

- Onsite Unit

Bridgeport Gas Processing Plant 55053 657 Combustion Turbine Texas 0.8 Dropped

- Onsite Unit

Bridgeport Gas Processing Plant 55053 658 Combustion Turbine Texas 0.8 Dropped

- Onsite Unit

Bridgeport Gas Processing Plant 55053 666 Combustion Turbine Texas 0.8 Dropped

- Onsite Unit

Bridgeport Gas Processing Plant 55053 667 Combustion Turbine Texas 0.8 Dropped

- Onsite Unit

Bridgeport Gas Processing Plant 55053 671 Combustion Turbine Texas 0.8 Dropped

- Onsite Unit

Inforum 54290 BUG1 Combustion Turbine Georgia 1.3 Dropped

- Onsite Unit

Athens Regional Medical Center 55319 CT1 Combustion Turbine Georgia 0.7 Dropped

- Onsite Unit

Athens Regional Medical Center 55319 CT3 Combustion Turbine Georgia 0.7 Dropped

- Onsite Unit

Athens Regional Medical Center 55319 STEG3 Combustion Turbine Georgia 0.8 Dropped

- Onsite Unit

Athens Regional Medical Center 55319 STEG4 Combustion Turbine Georgia 0.8 Dropped

- Onsite Unit

Athens Regional Medical Center 55319 STEG5 Combustion Turbine Georgia 0.8 Dropped

- Onsite Unit

Athens Regional Medical Center 55319 STEG6 Combustion Turbine Georgia 0.8 Dropped

- Onsite Unit

Los Angeles Refinery Wilmington 54451 G1 Combustion Turbine California 6 Dropped

- Onsite Unit

Los Angeles Refinery Wilmington 54451 G2 Fossil Waste California 45 Dropped

- Onsite Unit

Texas City Plant Union Carbide 50153 GTG Combustion Turbine Texas 32 Dropped

- Onsite Unit

Texas City Plant Union Carbide 50153 STG Non

- Fossil Waste Texas 38 Dropped

- Onsite Unit

Saint Johns Health Center 50610 1 Combustion Turbine California 1 Dropped

- Onsite Unit

Indian Orchard Plant 1 10417 TG Coal Steam Massachusetts 3.2 Dropped

- Onsite Unit

Orca 789 3 Combustion Turbine Alaska 2.5 Dropped

- in Alaska or in Hawaii

Orca 789 4 Combustion Turbine Alaska 2.4 Dropped

- in Alaska or in Hawaii

Orca 789 5 Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Orca 789 6 Combustion Turbine Alaska 1.1 Dropped

- in Alaska or in Hawaii

Orca 789 7 Combustion Turbine Alaska 3.6 Dropped

- in Alaska or in Hawaii

Humpback Creek 7042 1 Hydro Alaska 0.4 Dropped

- in Alaska or in Hawaii

Humpback Creek 7042 2 Hydro Alaska 0.4 Dropped

- in Alaska or in Hawaii

## 166 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Humpback Creek 7042 3 Hydro Alaska 0.2 Dropped

- in Alaska or in Hawaii

Power Creek 7862 4 Hydro Alaska 2.8 Dropped

- in Alaska or in Hawaii

Power Creek 7862 5 Hydro Alaska 2.8 Dropped

- in Alaska or in Hawaii

LaFarge Alpena 50305 GE10 Coal Steam Michigan 3.2 Dropped

- Onsite Unit

LaFarge Alpena 50305 GEN6 Coal Steam Michigan 12 Dropped

- Onsite Unit

LaFarge Alpena 50305 GEN7 Coal Steam Michigan 10 Dropped

- Onsite Unit

LaFarge Alpena 50305 GEN8 Coal Steam Michigan 11 Dropped

- Onsite Unit

LaFarge Alpena 50305 GEN9 Coal Steam Michigan 11 Dropped

- Onsite Unit

Whiting Refinery 52130 15TG Fossil Waste Indiana 5 Dropped

- Onsite Unit

Whiting Refinery 52130 31TG Fossil Waste Indiana 11.2 Dropped

- Onsite Unit

Whiting Refinery 52130 32TG Fossil Waste Indiana 11.2 Dropped

- Onsite Unit

Whiting Refinery 52130 33TG Fossil Waste Indiana 16.4 Dropped

- Onsite Unit

Whiting Refinery 52130 34TG Fossil Waste Indiana 11.8 Dropped

- Onsite Unit

Whiting Refinery 52130 35TG Fossil Waste Indiana 38 Dropped

- Onsite Unit

Richmond Refinery TG800 52105 GEN5 Fossil Waste California 30.4 Dropped

- Onsite Unit

Richmond Cogen 52109 GEN1 Combustion Turbine California 50 Dropped

- Onsite Unit

Richmond Cogen 52109 GEN2 Combustion Turbine California 50 Dropped

- Onsite Unit

HGST San Jose Standby Generator 50024 50MW Combustion Turbine California 42 Dropped

- Onsite Unit

Millinocket Mill 55829 M1S1 O/G Steam Maine 14.5 Dropped

- Onsite Unit

Millinocket Mill 55829 M1S2 O/G Steam Maine 14.5 Dropped

- Onsite Unit

Millinocket Mill 55829 M1S3 O/G Steam Maine 29.3 Dropped

- Onsite Unit

Millinocket Mill 55829 M1S4 O/G Steam Maine 21.8 Dropped

- Onsite Unit

East Millinocket Mill 55830 M2S1 Biomass Maine 14.5 Dropped

- Onsite Unit

East Millinocket Mill 55830 M2S2 Biomass Maine 14.5 Dropped

- Onsite Unit

East Millinocket Mill 55830 M2S3 Biomass Maine 28.1 Dropped

- Onsite Unit

Harford Waste to Energy Facility 54935 1 Municipal Solid Waste Maryland 1.1 Dropped

- Onsite Unit

Yates Gas Plant 55025 GEN1 Combustion Turbine Texas 2.8 Dropped

- Onsite Unit

Yates Gas Plant 55025 GEN2 Combustion Turbine Texas 2.8 Dropped

- Onsite Unit

Cadbury Adams

- Rockford 54933 GEN1 Combustion Turbine Illinois 5 Dropped

- Onsite Unit

Rhinelander Mill 50933 GEN3 O/G Steam Wisconsin 0.6 Dropped

- Onsite Unit

## 167 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Rhinelander Mill 50933 GEN5 O/G Steam Wisconsin 4 Dropped

- Onsite Unit

Rhinelander Mill 50933 GEN6 Coal Steam Wisconsin 6.3 Dropped

- Onsite Unit

Rhinelander Mill 50933 HYD1 Hydro Wisconsin 0.5 Dropped

- Onsite Unit

Rhinelander Mill 50933 HYD2 Hydro Wisconsin 0.5 Dropped

- Onsite Unit

Rhinelander Mill 50933 HYD3 Hydro Wisconsin 1 Dropped

- Onsite Unit

Columbia Flooring Melbourne 56182 Kato Biomass Arkansas 1.7 Dropped

- Onsite Unit

Colville Indian Plywood & Veneer 56191 Gen1 Biomass Washington 5 Dropped

- Onsite Unit

Colville Indian Plywood & Veneer 56191 Gen2 Biomass Washington 7.5 Dropped

- Onsite Unit

Georgia Pacific Wauna Mill 56192 1 Non

- Fossil Waste Oregon 22 Dropped

- Onsite Unit

H Power 10334 GEN1 Municipal Solid Waste Hawaii 60 Dropped

- in Alaska or in Hawaii

American Eagle Paper Mills 50284 TG3 Coal Steam Pennsylvania 2.5 Dropped

- Onsite Unit

American Eagle Paper Mills 50284 TG4 Coal Steam Pennsylvania 4.5 Dropped

- Onsite Unit

American Eagle Paper Mills 50284 TG5 Coal Steam Pennsylvania 3 Dropped

- Onsite Unit

American Eagle Paper Mills 50284 TG6 Coal Steam Pennsylvania 7 Dropped

- Onsite Unit

Decorative Panels Intl 10149 GEN1 Coal Steam Michigan 6.8 Dropped

- Onsite Unit

Lincoln Paper & Tissue 54587 TG

- 3 Non

- Fossil Waste Maine 9 Dropped

- Onsite Unit

Lincoln Paper & Tissue 54587 WEST Non

- Fossil Waste Maine 3.5 Dropped

- Onsite Unit

Veolia Energy

- OKC 56246 EMG1 Combustion Turbine Oklahoma 0.3 Dropped

- Onsite Unit

Veolia Energy

- OKC 56246 EMG3 Combustion Turbine Oklahoma 0.3 Dropped

- Onsite Unit

Brunswick Cellulose 10605 GEN3 Non

- Fossil Waste Georgia 9.2 Dropped

- Onsite Unit

Brunswick Cellulose 10605 GEN4 Non

- Fossil Waste Georgia 50 Dropped

- Onsite Unit

Brunswick Cellulose 10605 GEN5 Non

- Fossil Waste Georgia 13 Dropped

- Onsite Unit

Camden South Carolina 10795 GEN1 Coal Steam South Carolina 5.5 Dropped

- Onsite Unit

Camden South Carolina 10795 GEN2 Coal Steam South Carolina 5.5 Dropped

- Onsite Unit

Camden South Carolina 10795 GEN3 Coal Steam South Carolina 17.5 Dropped

- Onsite Unit

Salem Harbor 1626 1 Coal Steam Massachusetts 79.7 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Salem Harbor 1626 2 Coal Steam Massachusetts 78 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Salem Harbor 1626 3 Coal Steam Massachusetts 149.8 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Salem Harbor 1626 4 O/G Steam Massachusetts 436.8 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Neenah Paper Munising Mill 54867 M387 Coal Steam Michigan 5.8 Dropped

- Onsite Unit

## 168 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

PPG Natrium Plant 50491 GEN3 Coal Steam West Virginia 7.5 Dropped

- Onsite Unit

PPG Natrium Plant 50491 GEN4 Coal Steam West Virginia 7.5 Dropped

- Onsite Unit

PPG Natrium Plant 50491 GEN6 Coal Steam West Virginia 26 Dropped

- Onsite Unit

PPG Natrium Plant 50491 GEN7 Coal Steam West Virginia 82 Dropped

- Onsite Unit

PPG Industries Works 14 54360 PORT Combustion Turbine Illinois 0.7 Dropped

- Onsite Unit

PPG Industries Works 14 54360 TK1 Combustion Turbine Illinois 2 Dropped

- Onsite Unit

PPG Industries Works 14 54360 TK2 Combustion Turbine Illinois 2 Dropped

- Onsite Unit

PPG Industries Shelby NC Works 54363 GEN2 Combustion Turbine North Carolina 0.6 Dropped

- Onsite Unit

PPG Industries Shelby NC Works 54363 GEN3 Combustion Turbine North Carolina 0.6 Dropped

- Onsite Unit

PPG Industries Shelby NC Works 54363 GEN4 Combustion Turbine North Carolina 0.8 Dropped

- Onsite Unit

PPG Industries Shelby NC Works 54363 GEN5 Combustion Turbine North Carolina 0.8 Dropped

- Onsite Unit

PPG Industries Works 4 54364 L1G Combustion Turbine Texas 2 Dropped

- Onsite Unit

PPG Industries Works 4 54364 L1PG Combustion Turbine Texas 0.9 Dropped

- Onsite Unit

PPG Industries Works 4 54364 L2G Combustion Turbine Texas 2 Dropped

- Onsite Unit

PPG Industries Works 4 54364 L2PG Combustion Turbine Texas 1.1 Dropped

- Onsite Unit

Santa Maria EPG 56284 EPG Fossil Waste California 5.5 Dropped

- Onsite Unit

Medford Operation 56193 1 Biomass Oregon 3.1 Dropped

- Onsite Unit

Medford Operation 56193 2 Biomass Oregon 4.4 Dropped

- Onsite Unit

Bayway Refinery 56294 FGX Non

- Fossil Waste New Jersey 11.2 Dropped

- Onsite Unit

Luke Mill 50282 GEN1 Coal Steam Maryland 32 Dropped

- Onsite Unit

Luke Mill 50282 GEN2 Coal Steam Maryland 28 Dropped

- Onsite Unit

Rock

- Tenn Mill 54763 2TG Non

- Fossil Waste Alabama 8.6 Dropped

- Onsite Unit

Rock

- Tenn Mill 54763 3TG Non

- Fossil Waste Alabama 16 Dropped

- Onsite Unit

Sunoco Eagle Point Refinery 55113 TR1 Fossil Waste New Jersey 7 Dropped

- Onsite Unit

Sunoco Eagle Point Refinery 55113 TR2 Fossil Waste New Jersey 7 Dropped

- Onsite Unit

Sunoco Eagle Point Refinery 55113 TR3 Fossil Waste New Jersey 7 Dropped

- Onsite Unit

Dekalb Medical Center 54830 3 Combustion Turbine Georgia 1.2 Dropped

- Onsite Unit

Dekalb Medical Center 54830 90 Combustion Turbine Georgia 1.2 Dropped

- Onsite Unit

Dekalb Medical Center 54830 93 Combustion Turbine Georgia 1.2 Dropped

- Onsite Unit

DeKalb Medical Center

- Hillandale 56231 1 Combustion Turbine Georgia 0.7 Dropped

- Onsite Unit

## 169 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

DeKalb Medical Center

- Hillandale 56231 2 Combustion Turbine Georgia 0.7 Dropped

- Onsite Unit

Jameson Gas Processing Plant 55052 620 Combustion Turbine Texas 0.3 Dropped

- Onsite Unit

Jameson Gas Processing Plant 55052 621 Combustion Turbine Texas 0.3 Dropped

- Onsite Unit

Jameson Gas Processing Plant 55052 622 Combustion Turbine Texas 0.5 Dropped

- Onsite Unit

Terra Mississippi Nitrogen 10195 EXIS Combustion Turbine Mississippi 21.3 Dropped

- Onsite Unit

Georgia Pacific Palatka Operations 10611 GEN2 O/G Steam Florida 7 Dropped

- Onsite Unit

Georgia Pacific Palatka Operations 10611 GEN4 Non

- Fossil Waste Florida 44.6 Dropped

- Onsite Unit

Georgia Pacific Palatka Operations 10611 GEN8 Non

- Fossil Waste Florida 25.1 Dropped

- Onsite Unit

Georgia Pacific Port Hudson 10612 GEN1 Non

- Fossil Waste Louisiana 67.7 Dropped

- Onsite Unit

Georgia Pacific Port Hudson 10612 GEN2 Coal Steam Louisiana 60 Dropped

- Onsite Unit

Valero Energy Port Arthur Refinery 52108 GEN1 Combined Cycle Texas 14 Dropped

- Onsite Unit

Valero Energy Port Arthur Refinery 52108 GEN2 Combined Cycle Texas 12 Dropped

- Onsite Unit

Valero Energy Port Arthur Refinery 52108 GEN4 Combined Cycle Texas 10 Dropped

- Onsite Unit

Valero Energy Port Arthur Refinery 52108 GEN5 Combined Cycle Texas 10 Dropped

- Onsite Unit

Valero Energy Port Arthur Refinery 52108 GEN6 Combined Cycle Texas 10 Dropped

- Onsite Unit

Valero Energy Port Arthur Refinery 52108 GEN7 Combined Cycle Texas 10 Dropped

- Onsite Unit

Solo Cup Co 56040 1 Combustion Turbine Maryland 5.6 Dropped

- Onsite Unit

Solo Cup Co 56040 2 Combustion Turbine Maryland 5.6 Dropped

- Onsite Unit

MPEA Energy Center 55067 GEN1 Combustion Turbine Illinois 1.1 Dropped

- Onsite Unit

MPEA Energy Center 55067 GEN2 Combustion Turbine Illinois 1.1 Dropped

- Onsite Unit

MPEA Energy Center 55067 GEN3 Combustion Turbine Illinois 1.1 Dropped

- Onsite Unit

MPEA Energy Center 55067 GEN4 Combustion Turbine Illinois 2 Dropped

- Onsite Unit

MPEA Energy Center 55067 GEN5 Combustion Turbine Illinois 2 Dropped

- Onsite Unit

MPEA Energy Center 55067 GEN6 Combustion Turbine Illinois 2 Dropped

- Onsite Unit

Seadrift Coke LP 10167 GEN1 Coal Steam Texas 7.6 Dropped

- Onsite Unit

International Paper Kaukauna Mill 54098 GEN1 Non

- Fossil Waste Wisconsin 6 Dropped

- Onsite Unit

International Paper Kaukauna Mill 54098 GEN2 Non

- Fossil Waste Wisconsin 11 Dropped

- Onsite Unit

International Paper Kaukauna Mill 54098 GEN3 Non

- Fossil Waste Wisconsin 15.6 Dropped

- Onsite Unit

International Paper Kaukauna Mill 54098 GEN4 Coal Steam Wisconsin 12 Dropped

- Onsite Unit

TempleInland 10425 TG Non

- Fossil Waste Texas 36.8 Dropped

- Onsite Unit

## 170 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Kyocera America Project 10720 85 Combustion Turbine California 0.7 Dropped

- Onsite Unit

Kyocera America Project 10720 88 Combustion Turbine California 0.7 Dropped

- Onsite Unit

Kyocera America Project 10720 95 Combustion Turbine California 0.8 Dropped

- Onsite Unit

Kyocera America Project 10720 96 Combustion Turbine California 0.7 Dropped

- Onsite Unit

Chocolate Bayou Works 10154 GEN1 Combustion Turbine Texas 30 Dropped

- Onsite Unit

Mead Rumford Cogen 10491 3STG O/G Steam Maine 12.5 Dropped

- Onsite Unit

Wailuku River Hydroelectric 54827 8101 Hydro Hawaii 4.9 Dropped

- in Alaska or in Hawaii

Wailuku River Hydroelectric 54827 8102 Hydro Hawaii 4.9 Dropped

- in Alaska or in Hawaii

Wausau Paper Mills LLC 50636 1 Hydro Minnesota 0.5 Dropped

- Onsite Unit

Wausau Paper Mills LLC 50636 2 Hydro Minnesota 0.5 Dropped

- Onsite Unit

Wausau Paper Mills LLC 50636 3 Hydro Minnesota 0.4 Dropped

- Onsite Unit

Wausau Paper Mills LLC 50636 4 Hydro Minnesota 0.6 Dropped

- Onsite Unit

Wausau Paper Mills LLC 50636 5 Hydro Minnesota 0.6 Dropped

- Onsite Unit

Wausau Paper Mills LLC 50636 VPLS Coal Steam Minnesota 0.4 Dropped

- Onsite Unit

Big Escambia Creek 50724 3011 O/G Steam Alabama 1.1 Dropped

- Onsite Unit

Big Escambia Creek 50724 3012 O/G Steam Alabama 1.1 Dropped

- Onsite Unit

Big Escambia Creek 50724 3023 O/G Steam Alabama 1.1 Dropped

- Onsite Unit

American Gypsum Cogeneration 54630 D

- 1 Combustion Turbine Colorado 1.2 Dropped

- Onsite Unit

American Gypsum Cogeneration 54630 D

- 2 Combustion Turbine Colorado 1.2 Dropped

- Onsite Unit

American Gypsum Cogeneration 54630 T

- 1 Combustion Turbine Colorado 2.6 Dropped

- Onsite Unit

American Gypsum Cogeneration 54630 T

- 2 Combustion Turbine Colorado 2.6 Dropped

- Onsite Unit

New Milford Gas Recovery 50564 GEN4 Landfill Gas Connecticut 0.8 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Monroe Livingston Gas Recovery 50565 GEN2 Landfill Gas New York 0.8 Dropped

- PLANNED_RETIREMENT_YEAR < =2015

BJ Gas Recovery 54392 GEN3 Landfill Gas Georgia 0.8 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Ridgeview 55925 GEN9 Landfill Gas Wisconsin 0.8 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Timberline Trail Gas Recovery 56525 GEN6 Landfill Gas Wisconsin 0.8 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Timberline Trail Gas Recovery 56525 GEN7 Landfill Gas Wisconsin 0.8 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

CID Gas Recovery 50573 GEN1 Landfill Gas Illinois 2.9 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Lake Gas Recovery 50575 GEN2 Landfill Gas Illinois 2.9 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Kaheawa Pastures Wind Farm 56449 1 Wind Hawaii 30 Dropped

- in Alaska or in Hawaii

## 171 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Flambeau River Papers 50620 GEN1 Biomass Wisconsin 4.7 Dropped

- Onsite Unit

P H Glatfelter Co

- Chillicothe Facility 10244 T

- 10 Non

- Fossil Waste Ohio 4.1 Dropped

- Onsite Unit

P H Glatfelter Co

- Chillicothe Facility 10244 T

- 11 Non

- Fossil Waste Ohio 10.8 Dropped

- Onsite Unit

P H Glatfelter Co

- Chillicothe Facility 10244 T

- 12 Non

- Fossil Waste Ohio 19.3 Dropped

- Onsite Unit

P H Glatfelter Co

- Chillicothe Facility 10244 T

- 13 Coal Steam Ohio 19.1 Dropped

- Onsite Unit

Glen Ferris Hydro 50010 GEN1 Hydro West Virginia 0.3 Dropped

- Onsite Unit

Glen Ferris Hydro 50010 GEN2 Hydro West Virginia 0.3 Dropped

- Onsite Unit

Glen Ferris Hydro 50010 GEN3 Hydro West Virginia 0.3 Dropped

- Onsite Unit

Glen Ferris Hydro 50010 GEN4 Hydro West Virginia 0.3 Dropped

- Onsite Unit

Glen Ferris Hydro 50010 GEN5 Hydro West Virginia 0.3 Dropped

- Onsite Unit

Glen Ferris Hydro 50010 GEN6 Hydro West Virginia 0.3 Dropped

- Onsite Unit

Glen Ferris Hydro 50010 GEN7 Hydro West Virginia 1.3 Dropped

- Onsite Unit

Glen Ferris Hydro 50010 GEN8 Hydro West Virginia 1.3 Dropped

- Onsite Unit

Otsego Mill Power Plant 55799 NRTH Combustion Turbine Michigan 8.8 Dropped

- Onsite Unit

Otsego Mill Power Plant 55799 SOTH Combustion Turbine Michigan 8.8 Dropped

- Onsite Unit

DEGS of Narrows LLC 52089 GEN1 Coal Steam Virginia 6 Dropped

- Onsite Unit

DEGS of Narrows LLC 52089 GEN2 Coal Steam Virginia 6 Dropped

- Onsite Unit

DEGS of Narrows LLC 52089 GEN3 Coal Steam Virginia 5 Dropped

- Onsite Unit

DEGS of Narrows LLC 52089 GEN4 Coal Steam Virginia 4 Dropped

- Onsite Unit

International Paper Jay Hydro 50047 GEN1 Hydro Maine 0.5 Dropped

- Onsite Unit

International Paper Jay Hydro 50047 GEN2 Hydro Maine 0.5 Dropped

- Onsite Unit

International Paper Jay Hydro 50047 GEN3 Hydro Maine 0.5 Dropped

- Onsite Unit

International Paper Jay Hydro 50047 GEN4 Hydro Maine 0.5 Dropped

- Onsite Unit

International Paper Jay Hydro 50047 GEN5 Hydro Maine 0.5 Dropped

- Onsite Unit

International Paper Jay Hydro 50047 GEN6 Hydro Maine 0.6 Dropped

- Onsite Unit

International Paper Livermore Hydro 50082 GEN1 Hydro Maine 1.1 Dropped

- Onsite Unit

International Paper Livermore Hydro 50082 GEN2 Hydro Maine 1.1 Dropped

- Onsite Unit

International Paper Livermore Hydro 50082 GEN3 Hydro Maine 1.1 Dropped

- Onsite Unit

International Paper Livermore Hydro 50082 GEN4 Hydro Maine 1.2 Dropped

- Onsite Unit

International Paper Livermore Hydro 50082 GEN5 Hydro Maine 1.1 Dropped

- Onsite Unit

## 172 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

International Paper Livermore Hydro 50082 GEN6 Hydro Maine 0.7 Dropped

- Onsite Unit

International Paper Livermore Hydro 50082 GEN7 Hydro Maine 0.9 Dropped

- Onsite Unit

International Paper Livermore Hydro 50082 GEN8 Hydro Maine 1 Dropped

- Onsite Unit

International Paper Livermore Hydro 50082 GEN9 Hydro Maine 1 Dropped

- Onsite Unit

Androscoggin Mill 54085 GEN1 Non

- Fossil Waste Maine 25 Dropped

- Onsite Unit

Androscoggin Mill 54085 GEN2 Non

- Fossil Waste Maine 25 Dropped

- Onsite Unit

Androscoggin Mill 54085 GEN3 Non

- Fossil Waste Maine 30 Dropped

- Onsite Unit

KapStone Kraft Paper Corp 50254 GEN1 Coal Steam North Carolina 25 Dropped

- Onsite Unit

Versailles Mill 54657 NO1 O/G Steam Connecticut 14 Dropped

- Onsite Unit

Kentucky Mills 55429 1 Non

- Fossil Waste Kentucky 49 Dropped

- Onsite Unit

Weyerhaeuser Kingsport Mill 10252 NO.1 Non

- Fossil Waste Tennessee 46.5 Dropped

- Onsite Unit

R & R Lumber 50945 ST1 Biomass Oregon 1.4 Dropped

- Onsite Unit

Pine Bluff Mill 10627 1TG1 Non

- Fossil Waste Arkansas 32 Dropped

- Onsite Unit

Pine Bluff Mill 10627 2TG1 Non

- Fossil Waste Arkansas 15 Dropped

- Onsite Unit

Pine Bluff Mill 10627 3TG1 Non

- Fossil Waste Arkansas 13 Dropped

- Onsite Unit

Escanaba Paper Company 10208 NO.7 Coal Steam Michigan 32 Dropped

- Onsite Unit

Escanaba Paper Company 10208 NO.8 Non

- Fossil Waste Michigan 23 Dropped

- Onsite Unit

Escanaba Paper Company 10208 NO9 Coal Steam Michigan 45 Dropped

- Onsite Unit

RG Steel Sparrows Point, LLC 10485 GEN1 Fossil Waste Maryland 152.3 Dropped

- Onsite Unit

RG Steel Sparrows Point, LLC 10485 GEN2 Fossil Waste Maryland Dropped

- Onsite Unit

RG Steel Sparrows Point, LLC 10485 GEN3 Fossil Waste Maryland Dropped

- Onsite Unit

RG Steel Sparrows Point, LLC 10485 GEN4 Fossil Waste Maryland Dropped

- Onsite Unit

Lanai Solar

- Electric Plant 56667 1 Solar PV Hawaii 0.1 Dropped

- in Alaska or in Hawaii

Lanai Solar

- Electric Plant 56667 2 Solar PV Hawaii 0.1 Dropped

- in Alaska or in Hawaii

Lanai Solar

- Electric Plant 56667 3 Solar PV Hawaii 0.1 Dropped

- in Alaska or in Hawaii

Lanai Solar

- Electric Plant 56667 4 Solar PV Hawaii 0.1 Dropped

- in Alaska or in Hawaii

Lanai Solar

- Electric Plant 56667 5 Solar PV Hawaii 0.1 Dropped

- in Alaska or in Hawaii

Lanai Solar

- Electric Plant 56667 6 Solar PV Hawaii 0.1 Dropped

- in Alaska or in Hawaii

Lanai Solar

- Electric Plant 56667 7 Solar PV Hawaii 0.1 Dropped

- in Alaska or in Hawaii

Lanai Solar

- Electric Plant 56667 8 Solar PV Hawaii 0.1 Dropped

- in Alaska or in Hawaii

## 173 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Lanai Solar

- Electric Plant 56667 9 Solar PV Hawaii 0.1 Dropped

- in Alaska or in Hawaii

Lanai Solar

- Electric Plant 56667 10 Solar PV Hawaii 0.1 Dropped

- in Alaska or in Hawaii

Lanai Solar

- Electric Plant 56667 11 Solar PV Hawaii 0.1 Dropped

- in Alaska or in Hawaii

Lanai Solar

- Electric Plant 56667 12 Solar PV Hawaii 0.1 Dropped

- in Alaska or in Hawaii

Green Bay West Mill 10360 GEN10 Coal Steam Wisconsin 26.4 Dropped

- Onsite Unit

Green Bay West Mill 10360 GEN5 Coal Steam Wisconsin 7.5 Dropped

- Onsite Unit

Green Bay West Mill 10360 GEN6 Coal Steam Wisconsin 18 Dropped

- Onsite Unit

Green Bay West Mill 10360 GEN7 Coal Steam Wisconsin 23 Dropped

- Onsite Unit

Green Bay West Mill 10360 GEN9 Coal Steam Wisconsin 38 Dropped

- Onsite Unit

Georgia Pacific Brewton Mill 54789 1TG Non

- Fossil Waste Alabama 10.2 Dropped

- Onsite Unit

Georgia Pacific Brewton Mill 54789 2TG Non

- Fossil Waste Alabama 12.4 Dropped

- Onsite Unit

Georgia Pacific Brewton Mill 54789 3TG Non

- Fossil Waste Alabama 14.1 Dropped

- Onsite Unit

Regional Wastewater Control Facility 56134 101 Non

- Fossil Waste California 1 Dropped

- Onsite Unit

Regional Wastewater Control Facility 56134 301 Non

- Fossil Waste California 1 Dropped

- Onsite Unit

Regional Wastewater Control Facility 56134 401 Non

- Fossil Waste California 1 Dropped

- Onsite Unit

Regional Wastewater Control Facility 56134 501 Combustion Turbine California 1 Dropped

- Onsite Unit

Biron Mill 10234 GEN1 Coal Steam Wisconsin 15.3 Dropped

- Onsite Unit

Biron Mill 10234 GEN3 Coal Steam Wisconsin 7.5 Dropped

- Onsite Unit

Biron Mill 10234 GEN4 Coal Steam Wisconsin 12.5 Dropped

- Onsite Unit

Biron Mill 10234 GEN5 Coal Steam Wisconsin 20 Dropped

- Onsite Unit

Wisconsin Rapids Paper Mill 10466 GEN1 Non

- Fossil Waste Wisconsin 7.5 Dropped

- Onsite Unit

Wisconsin Rapids Paper Mill 10466 GEN2 Non

- Fossil Waste Wisconsin 8.6 Dropped

- Onsite Unit

Wisconsin Rapids Paper Mill 10466 GEN3 Non

- Fossil Waste Wisconsin 5 Dropped

- Onsite Unit

Whiting Mill 10476 GEN4 Coal Steam Wisconsin 4.1 Dropped

- Onsite Unit

Duluth Paper Mill 50424 GEN1 Non

- Fossil Waste Minnesota 10.6 Dropped

- Onsite Unit

Niagara Mill 54857 1HY Hydro Wisconsin 1.8 Dropped

- Onsite Unit

Niagara Mill 54857 1ST Coal Steam Wisconsin 2.5 Dropped

- Onsite Unit

Niagara Mill 54857 2HY Hydro Wisconsin 2.2 Dropped

- Onsite Unit

Niagara Mill 54857 2ST Coal Steam Wisconsin 9.3 Dropped

- Onsite Unit

Niagara Mill 54857 3HY Hydro Wisconsin 2.6 Dropped

- Onsite Unit

## 174 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Niagara Mill 54857 4HY Hydro Wisconsin 2.6 Dropped

- Onsite Unit

Niagara Mill 54857 5HY Hydro Wisconsin 1 Dropped

- Onsite Unit

Niagara Mill 54857 6HY Hydro Wisconsin 2.5 Dropped

- Onsite Unit

Stevens Point Mill 55861 SP O/G Steam Wisconsin 7 Dropped

- Onsite Unit

Parkedale Pharmaceuticals 50318 38

- 1 Combustion Turbine Michigan 2.8 Dropped

- Onsite Unit

Catalyst Paper Snowflake Mill 50805 GEN1 Coal Steam Arizona 26 Dropped

- Onsite Unit

Catalyst Paper Snowflake Mill 50805 GEN2 Coal Steam Arizona 42 Dropped

- Onsite Unit

Equilon Los Angeles Refining 50530 GEN1 Fossil Waste California 25 Dropped

- Onsite Unit

Equilon Los Angeles Refining 50530 GEN2 Fossil Waste California 25 Dropped

- Onsite Unit

Equilon Los Angeles Refining 50530 GEN3 Fossil Waste California 15 Dropped

- Onsite Unit

Biosphere 2 Center 54594 G

- 1 Combustion Turbine Arizona 1.5 Dropped

- Onsite Unit

Biosphere 2 Center 54594 G

- 4 Combustion Turbine Arizona 1.6 Dropped

- Onsite Unit

Domtar Paper Company Rothschild 50190 HG1 Hydro Wisconsin 0.6 Dropped

- Onsite Unit

Domtar Paper Company Rothschild 50190 HG2 Hydro Wisconsin 0.5 Dropped

- Onsite Unit

Domtar Paper Company Rothschild 50190 HG3 Hydro Wisconsin 0.6 Dropped

- Onsite Unit

Domtar Paper Company Rothschild 50190 HG4 Hydro Wisconsin 0.5 Dropped

- Onsite Unit

Domtar Paper Company Rothschild 50190 HG5 Hydro Wisconsin 1 Dropped

- Onsite Unit

Domtar Paper Company Rothschild 50190 HG6 Hydro Wisconsin 0.7 Dropped

- Onsite Unit

Domtar Paper Company Rothschild 50190 HG7 Hydro Wisconsin 0.5 Dropped

- Onsite Unit

Domtar Paper Company Rothschild 50190 TG2 O/G Steam Wisconsin 4.7 Dropped

- Onsite Unit

Kamin LLC Wrens Plant 54880 SDT1 Combustion Turbine Georgia 1.7 Dropped

- Onsite Unit

Kamin LLC Wrens Plant 54880 SDT2 Combustion Turbine Georgia 1.7 Dropped

- Onsite Unit

Kamin LLC Wrens Plant 54880 SDT3 Combustion Turbine Georgia 1.7 Dropped

- Onsite Unit

Kamin LLC Wrens Plant 54880 WPH1 Combustion Turbine Georgia 1.1 Dropped

- Onsite Unit

Kamin LLC Wrens Plant 54880 WPH2 Combustion Turbine Georgia 1.2 Dropped

- Onsite Unit

Kamin LLC Wrens Plant 54880 WPH3 Combustion Turbine Georgia 1 Dropped

- Onsite Unit

Kamin LLC Wrens Mine 55961 WM1 Combustion Turbine Georgia 1 Dropped

- Onsite Unit

Kamin LLC Wrens Mine 55961 WM2 Combustion Turbine Georgia 1 Dropped

- Onsite Unit

International Paper Sartell Mill 50252 ABB2 Coal Steam Minnesota 20.4 Dropped

- Onsite Unit

International Paper Sartell Mill 50252 HG10 Hydro Minnesota 0.9 Dropped

- Onsite Unit

## 175 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

International Paper Sartell Mill 50252 HG11 Hydro Minnesota 0.9 Dropped

- Onsite Unit

International Paper Sartell Mill 50252 HG12 Hydro Minnesota 0.9 Dropped

- Onsite Unit

International Paper Sartell Mill 50252 HG2 Hydro Minnesota 0.9 Dropped

- Onsite Unit

International Paper Sartell Mill 50252 HG3 Hydro Minnesota 0.9 Dropped

- Onsite Unit

International Paper Sartell Mill 50252 HG4 Hydro Minnesota 0.9 Dropped

- Onsite Unit

International Paper Sartell Mill 50252 HG5 Hydro Minnesota 0.9 Dropped

- Onsite Unit

International Paper Sartell Mill 50252 HG6 Hydro Minnesota 0.8 Dropped

- Onsite Unit

International Paper Sartell Mill 50252 HG7 Hydro Minnesota 0.8 Dropped

- Onsite Unit

International Paper Sartell Mill 50252 HG8 Hydro Minnesota 0.7 Dropped

- Onsite Unit

International Paper Sartell Mill 50252 HG9 Hydro Minnesota 0.7 Dropped

- Onsite Unit

Elk Basin Gasoline Plant 52127 GEN1 O/G Steam Wyoming 0.8 Dropped

- Onsite Unit

Elk Basin Gasoline Plant 52127 GEN2 O/G Steam Wyoming 0.8 Dropped

- Onsite Unit

Noranda Alumina LLC 50846 GT1 Combustion Turbine Louisiana 15 Dropped

- Onsite Unit

Noranda Alumina LLC 50846 GT2 Combustion Turbine Louisiana 15 Dropped

- Onsite Unit

Noranda Alumina LLC 50846 GT3 Combustion Turbine Louisiana 15 Dropped

- Onsite Unit

Noranda Alumina LLC 50846 GT4 Combustion Turbine Louisiana 21 Dropped

- Onsite Unit

Noranda Alumina LLC 50846 ST1 O/G Steam Louisiana 17 Dropped

- Onsite Unit

Noranda Alumina LLC 50846 ST2 O/G Steam Louisiana 17 Dropped

- Onsite Unit

Noranda Alumina LLC 50846 ST3 O/G Steam Louisiana 6 Dropped

- Onsite Unit

Riverwood 100 Building 54816 11KT Combustion Turbine Georgia 1.1 Dropped

- Onsite Unit

Benedum Plant 54458 BG3A Combustion Turbine Texas 1 Dropped

- Onsite Unit

Benedum Plant 54458 BG6 Combustion Turbine Texas 1 Dropped

- Onsite Unit

Johnsonburg Mill 54638 PT1 Non

- Fossil Waste Pennsylvania 49 Dropped

- Onsite Unit

ArcelorMittal Burns Harbor 10245 GEN5 Fossil Waste Indiana 60.5 Dropped

- Onsite Unit

ArcelorMittal Burns Harbor 10245 GEN6 Fossil Waste Indiana 51 Dropped

- Onsite Unit

ArcelorMittal Burns Harbor 10245 GEN7 Fossil Waste Indiana 63.2 Dropped

- Onsite Unit

Expander Turbine 10475 16TG Fossil Waste Indiana 15 Dropped

- Onsite Unit

Dynegy South Bay Power Plant 310 2 O/G Steam California 150 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Dynegy South Bay Power Plant 310 5 Combustion Turbine California 14 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Dynegy South Bay Power Plant 310 ST1 O/G Steam California 146 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

## 176 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

International Paper Valliant OK 50192 TG1 Non

- Fossil Waste Oklahoma 57.8 Dropped

- Onsite Unit

ArcelorMittal Indiana Harbor West 10397 GEN5 Fossil Waste Indiana 3.1 Dropped

- Onsite Unit

ArcelorMittal Indiana Harbor West 10397 GEN6 Fossil Waste Indiana 3.1 Dropped

- Onsite Unit

ArcelorMittal Indiana Harbor West 10397 GEN7 Fossil Waste Indiana 3.9 Dropped

- Onsite Unit

ArcelorMittal Indiana Harbor West 10397 GEN8 Fossil Waste Indiana 3.9 Dropped

- Onsite Unit

ArcelorMittal Indiana Harbor West 10397 GEN9 Fossil Waste Indiana 11.9 Dropped

- Onsite Unit

Finch Paper 10511 GEN6 O/G Steam New York 23 Dropped

- Onsite Unit

Verso Paper Quinnesec Mich Mill 50251 GEN1 Non

- Fossil Waste Michigan 28 Dropped

- Onsite Unit

US DOE Savannah River Site (D Area) 7652 HP

- 1 Coal Steam South Carolina 9.4 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

US DOE Savannah River Site (D Area) 7652 HP

- 2 Coal Steam South Carolina 9.4 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

US DOE Savannah River Site (D Area) 7652 HP

- 3 Coal Steam South Carolina 9.4 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

US DOE Savannah River Site (D Area) 7652 LP

- 1 Coal Steam South Carolina 12.5 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

US DOE Savannah River Site (D Area) 7652 LP

- 2 Coal Steam South Carolina 12.5 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

US DOE Savannah River Site (D Area) 7652 LP

- 3 Coal Steam South Carolina 12.5 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

US DOE Savannah River Site (D Area) 7652 LP

- 4 Coal Steam South Carolina 12.5 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Clearwater Paper APP CB 50638 GEN1 Non

- Fossil Waste Arkansas 20 Dropped

- Onsite Unit

IP Springfield Oregon 50191 TG1 Non

- Fossil Waste Oregon 7.5 Dropped

- Onsite Unit

IP Springfield Oregon 50191 TG2 Non

- Fossil Waste Oregon 5 Dropped

- Onsite Unit

IP Springfield Oregon 50191 TG3 Non

- Fossil Waste Oregon 12.5 Dropped

- Onsite Unit

IP Springfield Oregon 50191 TG4 Non

- Fossil Waste Oregon 33 Dropped

- Onsite Unit

Weyerhaeuser Pine Hill Operations 54752 NO1 Biomass Alabama 40 Dropped

- Onsite Unit

Weyerhaeuser Pine Hill Operations 54752 NO2 Non

- Fossil Waste Alabama 30.6 Dropped

- Onsite Unit

Pasadena 10638 GEN1 Combustion Turbine Texas 2.6 Dropped

- Onsite Unit

Boise Cascade Pulp & Paper Mill 55044 STG1 O/G Steam Alabama 17.8 Dropped

- Onsite Unit

Covanta WBH LLC 50660 GEN1 Municipal Solid Waste Oklahoma 15.6 Dropped

- Onsite Unit

Ashland Inc 10207 GEN1 Coal Steam Missouri 8.6 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Ashland Inc 10207 GEN2 Coal Steam Missouri 8.6 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Utility Plants Section 50308 GEN1 Coal Steam Alaska 24 Dropped

- Onsite Unit

Utility Plants Section 50308 GEN2 Coal Steam Alaska Dropped

- Onsite Unit

Utility Plants Section 50308 GEN3 Coal Steam Alaska Dropped

- Onsite Unit

## 177 Plant Name ORIS

Plant

Code Unit ID Plant Type State Name Capacity

(MW) Notes

Utility Plants Section 50308 GEN4 Coal Steam Alaska Dropped

- Onsite Unit

Utility Plants Section 50308 GEN5 Coal Steam Alaska Dropped

- Onsite Unit

Pulp Mill Power House 10074 GEN1 Non

- Fossil Waste California 20 Dropped

- Onsite Unit

Chalmette Refining LLC 50626 GEN1 Non

- Fossil Waste Louisiana 1.2 Dropped

- Onsite Unit

DTE Pontiac North LLC 10111 GEN1 Coal Steam Michigan 19 Dropped

- Onsite Unit

Red Shield Environmental Old Town Facili 10700 TG2 O/G Steam Maine 3 Dropped

- Onsite Unit

Red Shield Environmental Old Town Facili 10700 TG4 Non

- Fossil Waste Maine 7.5 Dropped

- Onsite Unit

Red Shield Environmental Old Town Facili 10700 TG5 Combustion Turbine Maine 8.8 Dropped

- Onsite Unit

Red Shield Environmental Old Town Facili 10700 TG6 Biomass Maine 14 Dropped

- Onsite Unit

Warner Lambert 54604 016E Combustion Turbine Michigan 1 Dropped

- Onsite Unit

Warner Lambert 54604 550 Combustion Turbine Michigan 1.5 Dropped

- Onsite Unit

Warner Lambert 54604 085

- 1 Combustion Turbine Michigan 2.3 Dropped

- Onsite Unit

Warner Lambert 54604 085

- 2 Combustion Turbine Michigan 2.3 Dropped

- Onsite Unit

Warner Lambert 54604 5164 Combustion Turbine Michigan 2.8 Dropped

- Onsite Unit

Warner Lambert 54604 800

- 1 Combustion Turbine Michigan 2.3 Dropped

- Onsite Unit

Chocolate Bayou Plant 10418 GEN1 Fossil Waste Texas 5.2 Dropped

- Onsite Unit

Chocolate Bayou Plant 10418 GEN4 Fossil Waste Texas 42.5 Dropped

- Onsite Unit

St Francisville Mill 10697 GEN2 Non

- Fossil Waste Louisiana 16.5 Dropped

- Onsite Unit

Evonik Degussa Tippecanoe Laboratories 54835 T121 Combustion Turbine Indiana 1.2 Dropped

- Onsite Unit

Union Tribune Publishing 10600 GEN1 Combustion Turbine California 3.1 Dropped

- Onsite Unit

WCI Steel 54207 GEN1 Fossil Waste Ohio 2.8 Dropped

- Onsite Unit

WCI Steel 54207 GEN2 Fossil Waste Ohio 7 Dropped

- Onsite Unit

WCI Steel 54207 GEN3 Fossil Waste Ohio 9.3 Dropped

- Onsite Unit

Empire 50760 OE11 Geothermal Nevada 0.9 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Empire 50760 OE12 Geothermal Nevada 0.9 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Empire 50760 OE13 Geothermal Nevada 0.9 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Empire 50760 OE14 Geothermal Nevada 0.9 Dropped

- PLANNED_RETIREMENT_YEAR <=2015

Kapaa Photovoltaic Project 57525 KSPV Solar PV Hawaii 1 Dropped

- in Alaska or in Hawaii

## 178 Table 4

‐ 36 Capacity Not Included Due to Recent Announcements

Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

5 in 1 Dam Hydroelectric 10171 GEN1 Hydro Iowa 0.7 2015

5 in 1 Dam Hydroelectric 10171 GEN2 Hydro Iowa 0.7 2015

5 in 1 Dam Hydroelectric 10171 GEN3 Hydro Iowa 0.7 2015

Abilene Energy Center Combustion Turbine 1251 GT1 Combustion Turbine Kansas 64 2013

ACE Cogeneration Facility 10002 CFB Coal Steam California 101 2016

AES Greenidge LLC 2527 6 Coal Steam New York 108 2012

AES Huntington Beach LLC 335 3A O/G Steam California 225 2012

AES Huntington Beach LLC 335 4A O/G Steam California 227 2012

AES Thames 10675 A Coal Steam Connecticut 90 2011

AES Thames 10675 B Coal Steam Connecticut 90 2011

AES Westover 2526 13 Coal Steam New York 84 2012

Air Products Port Arthur 55309 GEN2 Combined Cycle Texas 3 2012

Albany 2113 3 Combustion Turbine Missouri 0.6 2015

Algodones 2475 1 O/G Steam New Mexico 15 1987

Algodones 2475 2 O/G Steam New Mexico 15 1987

Algodones 2475 3 O/G Steam New Mexico 15 1987

Algonquin Power Sanger LLC 57564 STG Combined Cycle California 12.5 2012

Alliant Techsystems 7376 1 Combustion Turbine Minnesota 1.6 2013

Alloy Steam Station 50012 BLR4 Coal Steam West Virginia 38 2007

Alma 4140 B1 Coal Steam Wisconsin 17.4 2013

Alma 4140 B2 Coal Steam Wisconsin 17.4 2013

Alma 4140 B3 Coal Steam Wisconsin 20.9 2013

Alma 4140 B4 Coal Steam Wisconsin 48 2016

Alma 4140 B5 Coal Steam Wisconsin 72 2016

Alvarado Hydro Facility 54242 AHF Hydro California 1.4 2011

Animas 2465 3 O/G Steam New Mexico 9 2012

Animas 2465 4 O/G Steam New Mexico 16 2012

Asbury 2076 1 Coal Steam Missouri 189 2014

Astoria Generating Station 8906 20 O/G Steam New York 181 2012

Austin Northeast 1961 NEPP Coal Steam Minnesota 29 2015

Avon Energy Partners LLC 55768 CH2 Landfill Gas Illinois 0.9 2008

Avon Park 624 P1 Combustion Turbine Florida 24 2016

Avon Park 624 P2 Combustion Turbine Florida 24 2016

B C Cobb 1695 1 O/G Steam Michigan 62 2015

B C Cobb 1695 2 O/G Steam Michigan 62 2016

B C Cobb 1695 3 O/G Steam Michigan 62 2015

B C Cobb 1695 4 Coal Steam Michigan 156 2016

B C Cobb 1695 5 Coal Steam Michigan 156 2016

B L England 2378 1 Coal Steam New Jersey 113 2014

## 179 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

B L England 2378 IC1 Combustion Turbine New Jersey 2 2016

B L England 2378 IC2 Combustion Turbine New Jersey 2 2016

B L England 2378 IC3 Combustion Turbine New Jersey 2 2016

B L England 2378 IC4 Combustion Turbine New Jersey 2 2016

Balefill LFG Project 55159 UNT1 Landfill Gas New Jersey 0.1 2010

Balefill LFG Project 55159 UNT2 Landfill Gas New Jersey 0.1 2010

Barnett Shoals 701 1 Hydro Georgia 0.2 2010

Barnett Shoals 701 2 Hydro Georgia 0.2 2010

Barnett Shoals 701 3 Hydro Georgia 0.2 2010

Barnett Shoals 701 4 Hydro Georgia 0.2 2010

Barney M Davis 4939 2 Combined Cycle Texas 347 2009

Battle Mountain 6509 1 Combustion Turbine Nevada 1.8 2011

Battle Mountain 6509 2 Combustion Turbine Nevada 1.8 2011

Battle Mountain 6509 3 Combustion Turbine Nevada 1.8 2011

Battle Mountain 6509 4 Combustion Turbine Nevada 1.8 2011

Ben French 3325 1 Coal Steam South Dakota 21.6 2014

Berlin 6565 3A Combustion Turbine Maryland 1.8 2015

Berlin Gorham 54639 GOR1 Hydro New

Hampshire 1.2 2015

Big Sandy 1353 BSU2 Coal Steam Kentucky 800 2015

Binghamton Cogen 55600 1 Combustion Turbine New York 42 2012

Biodyne Lyons 55060 1 Landfill Gas Illinois 0.9 2015

Biodyne Lyons 55060 2 Landfill Gas Illinois 0.9 2015

Biodyne Lyons 55060 4 Landfill Gas Illinois 0.9 2015

Biodyne Peoria 55057 1 Landfill Gas Illinois 0.8 2015

Biodyne Peoria 55057 2 Landfill Gas Illinois 0.8 2015

Biodyne Peoria 55057 4 Landfill Gas Illinois 0.8 2015

Biodyne Peoria 55057 5 Landfill Gas Illinois 0.8 2015

Biodyne Pontiac 55054 1 Landfill Gas Illinois 4.2 2015

Biodyne Pontiac 55054 3 Landfill Gas Illinois 4.2 2015

Biodyne Pontiac 55054 GEN2 Landfill Gas Illinois 4.2 2015

Biron 3971 6 Hydro Wisconsin 0.4 2015

BJ Gas Recovery 54392 GEN1 Landfill Gas Georgia 0.8 2013

Blanco Compressor Station 54221 1 O/G Steam New Mexico 1 2011

Blanco Compressor Station 54221 2 O/G Steam New Mexico 1 2011

Block Island 6567 19 Combustion Turbine Rhode Island 1 2012

Bluebonnet 55552 UNT2 Landfill Gas Texas 1 2015

Boralex Sherman LLC 50874 19425 Biomass Maine 21 2009

Boulevard 732 2 Combustion Turbine Georgia 14 2013

Boulevard 732 3 Combustion Turbine Georgia 14 2013

Bountiful City 3665 2 Combustion Turbine Utah 1.2 2011

Bountiful City 3665 3 Combustion Turbine Utah 1.2 2011

## 180 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

Bountiful City 3665 4 Combustion Turbine Utah 1 2011

Bountiful City 3665 5 Combustion Turbine Utah 1 2011

Bountiful City 3665 6 Combustion Turbine Utah 2.5 2011

Bountiful City 3665 7 Combustion Turbine Utah 0.1 2011

Bowen 703 6 Combustion Turbine Georgia 32 2013

Bridgeport Station 568 4 Combustion Turbine Connecticut 18.3 2013

Brookhaven Facility 55778 BH2 Landfill Gas New York 1.2 2012

Brookhaven Facility 55778 BH3 Landfill Gas New York 1.2 2012

Brookhaven Facility 55778 BH4 Landfill Gas New York 1.2 2012

Brunot Island 3096 1B Combustion Turbine Pennsylvania 15 2011

Brunot Island 3096 1C Combustion Turbine Pennsylvania 15 2011

Bryan 3561 3 O/G Steam Texas 12 2015

Bryan 3561 4 O/G Steam Texas 22 2015

Bryan 3561 5 O/G Steam Texas 25 2015

Bryan 3561 6 O/G Steam Texas 50 2015

Buck 2720 CT10 Combined Cycle North Carolina 0 2015

Buck 2720 ST12 Combined Cycle North Carolina 0 2015

Canadys Steam 3280 CAN1 Coal Steam South Carolina 105 2013

Canadys Steam 3280 CAN2 Coal Steam South Carolina 115 2014

Canadys Steam 3280 CAN3 Coal Steam South Carolina 180 2014

Cane Run 1363 4 Coal Steam Kentucky 155 2016

Cane Run 1363 5 Coal Steam Kentucky 168 2016

Cane Run 1363 6 Coal Steam Kentucky 240 2016

Cape Canaveral 609 PCC1 O/G Steam Florida 396 2010

Cape Canaveral 609 PCC2 O/G Steam Florida 396 2010

Cape Fear 2708 1 Combined Cycle North Carolina 11 2011

Cape Fear 2708 1A Combined Cycle North Carolina 11 2013

Cape Fear 2708 1B Combined Cycle North Carolina 11 2012

Cape Fear 2708 2 Combined Cycle North Carolina 7 2011

Cape Fear 2708 2A Combined Cycle North Carolina 11 2013

Cape Fear 2708 2B Combined Cycle North Carolina 11 2012

Cape Fear 2708 5 Coal Steam North Carolina 144 2012

Cape Fear 2708 6 Coal Steam North Carolina 172 2012

Carbon 3644 1 Coal Steam Utah 67 2015

Carbon 3644 2 Coal Steam Utah 105 2015

Cedar Station 2380 CED1 Combustion Turbine New Jersey 44 2015

Cedar Station 2380 CED2 Combustion Turbine New Jersey 22.3 2015

Central Ohio BioEnergy Plant #1 57513 COBE1 Non

- Fossil Waste Ohio 0.9 2011

CES Placerita Power Plant 10677 UNT2 Combined Cycle California 46 2015

CES Placerita Power Plant 10677 UNT3 Combined Cycle California 23 2015

Chalk Cliff Cogen 50003 GEN1 Combustion Turbine California 46 2015

## 181 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

Chamois 2169 1 Coal Steam Missouri 16 2013

Chamois 2169 2 Coal Steam Missouri 47 2013

Cherokee 469 3 Coal Steam Colorado 152 2016

Chesapeake 3803 1 Coal Steam Virginia 111 2014

Chesapeake 3803 10 Combustion Turbine Virginia 16 2011

Chesapeake 3803 2 Coal Steam Virginia 111 2015

Chesapeake 3803 7 Combustion Turbine Virginia 16 2011

Chesapeake 3803 8 Combustion Turbine Virginia 16 2011

Chesapeake 3803 9 Combustion Turbine Virginia 16 2011

Chicopee Electric 55590 1 Landfill Gas Massachusetts 0.9 2012

Chicopee Electric 55590 2 Landfill Gas Massachusetts 0.9 2012

Clewiston Sugar House 50482 B1 Biomass Florida 11.1 2004

Coal Canyon 226 1 Hydro California 0.9 2013

Cogen South 7737 B001 Coal Steam South Carolina 45 2011

Cogen South 7737 RB01 Coal Steam South Carolina 45 2011

Colbert 47 1 Coal Steam Alabama 178 2016

Colbert 47 2 Coal Steam Alabama 178 2016

Colbert 47 3 Coal Steam Alabama 178 2016

Colbert 47 4 Coal Steam Alabama 178 2016

Colbert 47 5 Coal Steam Alabama 472 2016

Coldwater 1819 3 Combustion Turbine Michigan 3.5 2012

Coleman 2158 IC1 Combustion Turbine Missouri 2 2011

Coleman 2158 IC2 Combustion Turbine Missouri 2.3 2011

Colorado Energy Nations Company 10003 BLR1 Coal Steam Colorado 8.1 2012

Condit 3846 1 Hydro Washington 7.7 2011

Condit 3846 2 Hydro Washington 7.4 2011

Conesville 2840 3 Coal Steam Ohio 165 2012

Conners Creek 1726 15 O/G Steam Michigan 58 2013

Conners Creek 1726 16 O/G Steam Michigan 58 2012

Conners Creek 1726 17 O/G Steam Michigan 58 2012

Conners Creek 1726 18 O/G Steam Michigan 58 2012

Conroe 55555 UNT1 Landfill Gas Texas 1 2012

Conroe 55555 UNT2 Landfill Gas Texas 1 2012

Conroe 55555 UNT3 Landfill Gas Texas 1 2012

Countyside Genco LLC 55773 CS1 Landfill Gas Illinois 1.3 2012

Countyside Genco LLC 55773 CS2 Landfill Gas Illinois 1.3 2012

Countyside Genco LLC 55773 CS3 Landfill Gas Illinois 1.3 2012

Countyside Genco LLC 55773 CS4 Landfill Gas Illinois 1.3 2012

Countyside Genco LLC 55773 CS5 Landfill Gas Illinois 1.3 2012

Countyside Genco LLC 55773 CS6 Landfill Gas Illinois 1.3 2012

Crawford 867 7 Coal Steam Illinois 213 2012

## 182 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

Crawford 867 8 Coal Steam Illinois 319 2012

Crosscut 143 1 O/G Steam Arizona 7.5 2015

Crosscut 143 2 O/G Steam Arizona 7.5 2015

Crosscut 143 3 O/G Steam Arizona 7.5 2015

Crosscut 143 4 O/G Steam Arizona 2.5 2015

Crosscut 143 5 O/G Steam Arizona 2.5 2015

Crosscut 143 6 O/G Steam Arizona 2.5 2015

Crystal River 628 3 Nuclear Florida 1028 2013

CTV Power Purchase Contract Trust 54300 SX1S Wind California 0.1 2015

Cutler 610 PCU5 O/G Steam Florida 68 2012

Cutler 610 PCU6 O/G Steam Florida 137 2012

Cytec 1, 2 & 3 56257 CY 1 Combustion Turbine Connecticut 2 2011

Cytec 1, 2 & 3 56257 CY 2 Combustion Turbine Connecticut 2 2011

Cytec 1, 2 & 3 56257 CY 3 Combustion Turbine Connecticut 2 2011

Dale 1385 1 Coal Steam Kentucky 23 2015

Dale 1385 2 Coal Steam Kentucky 23 2015

Dale 1385 3 Coal Steam Kentucky 74 2015

Dale 1385 4 Coal Steam Kentucky 75 2015

Dan River 2723 CT1 Combined Cycle North Carolina 0 2015

Dan River 2723 CT2 Combined Cycle North Carolina 0 2015

Dan River 2723 ST Combined Cycle North Carolina 0 2015

Danskammer Generating Station 2480 1 O/G Steam New York 66 2013

Danskammer Generating Station 2480 2 O/G Steam New York 62 2013

Danskammer Generating Station 2480 3 Coal Steam New York 138 2013

Danskammer Generating Station 2480 4 Coal Steam New York 237 2013

Danskammer Generating Station 2480 5 Combustion Turbine New York 2.5 2013

Danskammer Generating Station 2480 6 Combustion Turbine New York 2.5 2013

DeCordova 8063 1 O/G Steam Texas 818 2011

Deepwater 2384 1 O/G Steam New Jersey 78 2014

Deepwater 2384 8 Coal Steam New Jersey 81 2014

Delta 2051 1 O/G Steam Mississippi 90 2015

Delta 2051 2 O/G Steam Mississippi 87 2015

Devonshire Power Partners LLC 55761 DO3 Landfill Gas Illinois 1 2009

Devonshire Power Partners LLC 55761 DO4 Landfill Gas Illinois 1 2009

Devonshire Power Partners LLC 55761 DO5 Landfill Gas Illinois 1 2009

Dolphus M Grainger 3317 1 Coal Steam South Carolina 83 2013

Dolphus M Grainger 3317 2 Coal Steam South Carolina 83 2013

Dominoin

- Warren County 55939 ST02 Combined Cycle Virginia 0 2015

Dunbarton Energy Partners LP 55779 MA1 Landfill Gas New

Hampshire 0.6 2012

Dunbarton Energy Partners LP 55779 MA2 Landfill Gas New

Hampshire 0.6 2012

Dynegy Morro Bay LLC 259 1 O/G Steam California 163 2014

## 183 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

Dynegy Morro Bay LLC 259 2 O/G Steam California 163 2014

Dynegy Morro Bay LLC 259 3 O/G Steam California 337 2014

Dynegy Morro Bay LLC 259 4 O/G Steam California 336 2014

E F Barrett 2511 7 Combustion Turbine New York 16.6 2011

E S Joslin 3436 1 O/G Steam Texas 254 2005

Eagle Mountain 3489 1 O/G Steam Texas 115 2012

Eagle Mountain 3489 2 O/G Steam Texas 175 2012

Eagle Mountain 3489 3 O/G Steam Texas 375 2012

Eagle River 4062 1 Combustion Turbine Wisconsin 2.1 2011

Eagle River 4062 2 Combustion Turbine Wisconsin 2.1 2011

Eagle Valley 991 6 Coal Steam Indiana 99 2014

East Third Street Power Plant 10367 CB1302 Coal Steam California 18.7 2012

Eastport 1468 1 Combustion Turbine Maine 0.7 2014

Eastport 1468 2 Combustion Turbine Maine 0.7 2014

Eastport 1468 3 Combustion Turbine Maine 2 2014

Eckert Station 1831 1 Coal Steam Michigan 35 2016

Eckert Station 1831 2 Coal Steam Michigan 36 2016

Eckert Station 1831 3 Coal Steam Michigan 34 2016

Edgewater 4050 3 Coal Steam Wisconsin 70 2016

El Cajon 301 ENCI Combustion Turbine California 15 2013

El Centro 389 3 O/G Steam California 42 2010

El Segundo Power 330 3 O/G Steam California 325 2013

Elrama Power Plant 3098 1 Coal Steam Pennsylvania 93 2014

Elrama Power Plant 3098 2 Coal Steam Pennsylvania 93 2014

Elrama Power Plant 3098 3 Coal Steam Pennsylvania 103 2014

Elrama Power Plant 3098 4 Coal Steam Pennsylvania 171 2014

Endicott Station 4259 2 Combustion Turbine Michigan 1.6 2012

Endicott Station 4259 3 Combustion Turbine Michigan 1.6 2012

Enid 2950 1 Combustion Turbine Oklahoma 11.1 2012

Enid 2950 2 Combustion Turbine Oklahoma 10.5 2012

Enid 2950 3 Combustion Turbine Oklahoma 11.5 2012

Enid 2950 4 Combustion Turbine Oklahoma 10.5 2012

Estherville 1137 6 Combustion Turbine Iowa 1.7 2013

Everett Cogen 7627 14 Biomass Washington 36 2011

Fair Station 1218 1 Coal Steam Iowa 23 2013

Fair Station 1218 2 Coal Steam Iowa 41 2013

Fairview 2978 4 Combustion Turbine Oklahoma 0.8 2012

Fairview 2978 5 Combustion Turbine Oklahoma 1 2012

Far Rockaway 2513 40 O/G Steam New York 105 2012

FirstEnergy Albright 3942 1 Coal Steam West Virginia 73 2012

FirstEnergy Albright 3942 2 Coal Steam West Virginia 73 2012

## 184 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

FirstEnergy Albright 3942 3 Coal Steam West Virginia 137 2012

FirstEnergy Armstrong Power Station 3178 1 Coal Steam Pennsylvania 172 2012

FirstEnergy Armstrong Power Station 3178 2 Coal Steam Pennsylvania 172 2012

FirstEnergy Ashtabula 2835 7 Coal Steam Ohio 244 2015

FirstEnergy Bay Shore 2878 2 Coal Steam Ohio 138 2012

FirstEnergy Bay Shore 2878 3 Coal Steam Ohio 142 2012

FirstEnergy Bay Shore 2878 4 Coal Steam Ohio 215 2012

FirstEnergy Eastlake 2837 1 Coal Steam Ohio 132 2015

FirstEnergy Eastlake 2837 2 Coal Steam Ohio 132 2015

FirstEnergy Eastlake 2837 3 Coal Steam Ohio 132 2015

FirstEnergy Eastlake 2837 4 Coal Steam Ohio 240 2012

FirstEnergy Eastlake 2837 5 Coal Steam Ohio 597 2012

FirstEnergy Lake Shore 2838 18 Coal Steam Ohio 245 2015

FirstEnergy Mad River 2860 CTA Combustion Turbine Ohio 25 2014

FirstEnergy Mad River 2860 CTB Combustion Turbine Ohio 25 2014

FirstEnergy Mitchell Power Station 3181 1 O/G Steam Pennsylvania 27 2002

FirstEnergy Mitchell Power Station 3181 2 O/G Steam Pennsylvania 27 2013

FirstEnergy Mitchell Power Station 3181 3 O/G Steam Pennsylvania 27 2013

FirstEnergy Mitchell Power Station 3181 33 Coal Steam Pennsylvania 278 2013

FirstEnergy R E Burger 2864 5 Coal Steam Ohio 47 2012

FirstEnergy R Paul Smith Power Station 1570 11 Coal Steam Maryland 87 2012

FirstEnergy R Paul Smith Power Station 1570 9 Coal Steam Maryland 28 2012

FirstEnergy Rivesville 3945 7 Coal Steam West Virginia 37 2012

FirstEnergy Rivesville 3945 8 Coal Steam West Virginia 88 2012

FirstEnergy Willow Island 3946 1 Coal Steam West Virginia 54 2012

FirstEnergy Willow Island 3946 2 Coal Steam West Virginia 181 2012

Fisk Street 886 19 Coal Steam Illinois 326 2012

Four Corners 2442 1 Coal Steam New Mexico 170 2013

Four Corners 2442 2 Coal Steam New Mexico 170 2013

Four Corners 2442 3 Coal Steam New Mexico 220 2013

Fox Valley Energy Center 56037 1 Non

- Fossil Waste Wisconsin 6.5 2013

G E Turner 629 P1 Combustion Turbine Florida 10 2016

G E Turner 629 P2 Combustion Turbine Florida 10 2016

G W Ivey 665 10 Combustion Turbine Florida 2 2013

G W Ivey 665 11 Combustion Turbine Florida 3 2013

G W Ivey 665 12 Combustion Turbine Florida 3 2013

G W Ivey 665 18 Combustion Turbine Florida 8 2013

G W Ivey 665 8 Combustion Turbine Florida 2 2013

G W Ivey 665 9 Combustion Turbine Florida 2 2013

Galena 3 Geothermal Power Plant 56541 GEN2 Geothermal Nevada 7.9 2015

Gantt 53 3 Hydro Alabama 1 2015

## 185 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

Garden City 1336 GC3 O/G Steam Kansas 8.7 2011

Gastonia Duke Street 56061 1 Combustion Turbine North Carolina 1.8 2012

Gastonia Rankin Lake 56060 1 Combustion Turbine North Carolina 1.8 2012

Gaylord 1706 5 Combustion Turbine Michigan 14 2010

Geneva Generation Facility 56462 GEN6 Combustion Turbine Illinois 1.4 2011

Geysers Unit 5

- 20 286 U10 Geothermal California 30 2015

Geysers Unit 5

- 20 286 U9 Geothermal California 30 2015

Gilbert 2393 C1 Combustion Turbine New Jersey 23 2015

Gilbert 2393 C2 Combustion Turbine New Jersey 25 2015

Gilbert 2393 C3 Combustion Turbine New Jersey 25 2015

Gilbert 2393 C4 Combustion Turbine New Jersey 25 2015

Glen Gardner 8227 1 Combustion Turbine New Jersey 20 2015

Glen Gardner 8227 2 Combustion Turbine New Jersey 20 2015

Glen Gardner 8227 3 Combustion Turbine New Jersey 20 2015

Glen Gardner 8227 4 Combustion Turbine New Jersey 20 2015

Glen Gardner 8227 5 Combustion Turbine New Jersey 20 2015

Glen Gardner 8227 6 Combustion Turbine New Jersey 20 2015

Glen Gardner 8227 7 Combustion Turbine New Jersey 20 2015

Glen Gardner 8227 8 Combustion Turbine New Jersey 20 2015

Glen Lyn 3776 51 Coal Steam Virginia 45 2015

Glen Lyn 3776 52 Coal Steam Virginia 45 2015

Glen Lyn 3776 6 Coal Steam Virginia 235 2015

Grand Forks 2821 1 Combustion Turbine North Dakota 0.7 2012

Grand Forks 2821 10 Combustion Turbine North Dakota 1.1 2012

Grand Forks 2821 11 Combustion Turbine North Dakota 1.1 2012

Grand Forks 2821 2 Combustion Turbine North Dakota 0.7 2012

Grand Forks 2821 3 Combustion Turbine North Dakota 0.7 2012

Grand Forks 2821 4 Combustion Turbine North Dakota 1 2012

Grand Forks 2821 5 Combustion Turbine North Dakota 1 2012

Grand Forks 2821 6 Combustion Turbine North Dakota 1 2012

Grand Forks 2821 7 Combustion Turbine North Dakota 1.1 2012

Grand Forks 2821 8 Combustion Turbine North Dakota 1.1 2012

Grand Forks 2821 9 Combustion Turbine North Dakota 1.1 2012

Great Bend 1334 6 Combustion Turbine Kansas 3 2012

Green River 1357 4 Coal Steam Kentucky 68 2015

Green River 1357 5 Coal Steam Kentucky 95 2016

Greene Energy Resource Recovery Project 56664 1 Coal Steam Pennsylvania 525 2016

Greenport 2681 2 Combustion Turbine New York 1.5 2015

Greenport 2681 7 Combustion Turbine New York 1.6 2015

Groveton Paper Board 56140 TUR1 Combustion Turbine New

Hampshire 4 2012

Groveton Paper Board 56140 TUR2 Combustion Turbine New

Hampshire 4 2012

## 186 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

H B Robinson 3251 1 Coal Steam South Carolina 177 2012

H B Robinson 3251 GT1 Combustion Turbine South Carolina 11 2013

Hamilton 2917 GT1 Combustion Turbine Ohio 8 2011

Hamilton Moses 168 1 O/G Steam Arkansas 67 2013

Hamilton Moses 168 2 O/G Steam Arkansas 67 2013

Hanford 10373 CB1302 Coal Steam California 25 2012

Hansel 672 21 Combined Cycle Florida 30 2012

Hansel 672 22 Combined Cycle Florida 8 2012

Hansel 672 23 Combined Cycle Florida 8 2012

Harbor Beach 1731 1 Coal Steam Michigan 95 2016

Harding Street 990 10 O/G Steam Indiana 35 2015

Harllee Branch 709 3 Coal Steam Georgia 509 2015

Harllee Branch 709 4 Coal Steam Georgia 507 2015

Harvey Couch 169 1 O/G Steam Arkansas 12 2011

Harwood 2822 2 Combustion Turbine North Dakota 1.6 2012

Harwood 2822 3 Combustion Turbine North Dakota 1.6 2012

Hatfields Ferry Power Station 3179 1 Coal Steam Pennsylvania 506 2013

Hatfields Ferry Power Station 3179 2 Coal Steam Pennsylvania 506 2013

Hatfields Ferry Power Station 3179 3 Coal Steam Pennsylvania 506 2013

Havana 891 1 O/G Steam Illinois 28 2013

Havana 891 2 O/G Steam Illinois 28 2013

Havana 891 3 O/G Steam Illinois 28 2013

Havana 891 4 O/G Steam Illinois 28 2013

Havana 891 5 O/G Steam Illinois 28 2013

Havana 891 6 O/G Steam Illinois 28 2013

Havana 891 7 O/G Steam Illinois 28 2013

Havana 891 8 O/G Steam Illinois 28 2013

Haynes 400 5 O/G Steam California 292 2013

Haynes 400 6 O/G Steam California 238 2013

Heber City 7111 NA3 Combustion Turbine Utah 0.6 2012

Herington 1283 1 Combustion Turbine Kansas 1.6 2012

Herington 1283 2 Combustion Turbine Kansas 1 2012

Herington 1283 3 Combustion Turbine Kansas 3.1 2012

Herington 1283 5 Combustion Turbine Kansas 0.9 2012

Herkimer 52057 1 Hydro New York 0.1 2015

Herkimer 52057 2 Hydro New York 0.1 2015

Herkimer 52057 3 Hydro New York 0.1 2015

Herkimer 52057 4 Hydro New York 0.1 2015

Higgins 630 P1 Combustion Turbine Florida 25 2016

Higgins 630 P2 Combustion Turbine Florida 25 2016

Higgins 630 P3 Combustion Turbine Florida 33 2016

## 187 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

Higgins 630 P4 Combustion Turbine Florida 30 2016

High Street Station 1670 3 Combustion Turbine Massachusetts 0.7 2015

HMDC Kingsland Landfill 55604 UNT1 Landfill Gas New Jersey 0.1 2010

HMDC Kingsland Landfill 55604 UNT2 Landfill Gas New Jersey 0.1 2010

HMDC Kingsland Landfill 55604 UNT3 Landfill Gas New Jersey 0.1 2010

Holcomb Rock 56314 HG2 Hydro Virginia 0.2 2015

Holt Dam 12 1 Hydro Alabama 45 2016

Hutsonville 863 5 Coal Steam Illinois 75 2011

Hutsonville 863 6 Coal Steam Illinois 76 2011

Hutsonville 863 D1 Combustion Turbine Illinois 3 2011

Ina Road Water Pollution Control Fac 55257 1 Combustion Turbine Arizona 0.6 2013

Ina Road Water Pollution Control Fac 55257 2 Combustion Turbine Arizona 0.6 2013

Ina Road Water Pollution Control Fac 55257 3 Combustion Turbine Arizona 0.6 2013

Ina Road Water Pollution Control Fac 55257 4 Combustion Turbine Arizona 0.6 2013

Ina Road Water Pollution Control Fac 55257 5 Combustion Turbine Arizona 0.6 2013

Ina Road Water Pollution Control Fac 55257 6 Combustion Turbine Arizona 0.6 2013

Ina Road Water Pollution Control Fac 55257 7 Combustion Turbine Arizona 0.6 2013

Indian River Generating Station 594 1 Coal Steam Delaware 89 2011

Indian River Generating Station 594 2 Coal Steam Delaware 89 2010

Indian Trails Cogen 1 7384 1 O/G Steam Illinois 3.3 2010

Iola 1291 11 Combustion Turbine Kansas 2.1 2013

Iola 1291 12 Combustion Turbine Kansas 2 2013

Iola 1291 13 Combustion Turbine Kansas 2 2013

Ivy River Hydro 50890 GEN1 Hydro North Carolina 0.2 2015

Ivy River Hydro 50890 GEN2 Hydro North Carolina 0.2 2015

Ivy River Hydro 50890 GEN3 Hydro North Carolina 0.2 2015

Ivy River Hydro 50890 GEN4 Hydro North Carolina 0.2 2015

Ivy River Hydro 50890 GEN5 Hydro North Carolina 0.2 2015

Ivy River Hydro 50890 GEN6 Hydro North Carolina 0.2 2015

J C Weadock 1720 7 Coal Steam Michigan 155 2016

J C Weadock 1720 8 Coal Steam Michigan 151 2016

J R Whiting 1723 1 Coal Steam Michigan 97 2016

J R Whiting 1723 2 Coal Steam Michigan 101 2016

J R Whiting 1723 3 Coal Steam Michigan 124 2016

Jack Watson 2049 A Combustion Turbine Mississippi 33 2016

James De Young 1830 5 Coal Steam Michigan 27 2016

Jefferies 3319 3 Coal Steam South Carolina 152 2013

Jefferies 3319 4 Coal Steam South Carolina 150 2013

John R Kelly 664 JRK7 O/G Steam Florida 23.2 2016

John Sevier 3405 3 Coal Steam Tennessee 176 2016

John Sevier 3405 4 Coal Steam Tennessee 176 2016

## 188 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

John Street 1, 3, 4 & 5 56256 JS 1 Combustion Turbine Connecticut 2 2011

Kammer 3947 1 Coal Steam West Virginia 200 2015

Kammer 3947 2 Coal Steam West Virginia 200 2015

Kammer 3947 3 Coal Steam West Virginia 200 2015

Kanawha River 3936 1 Coal Steam West Virginia 200 2015

Kanawha River 3936 2 Coal Steam West Virginia 200 2015

Kaw 1294 1 O/G Steam Kansas 42 2013

Kaw 1294 2 O/G Steam Kansas 42 2013

Kaw 1294 3 O/G Steam Kansas 56 2013

Kearny 303 KEA1 Combustion Turbine California 16 2013

Kearny 303 KEA2 Combustion Turbine California 59 2013

Kearny 303 KEA3 Combustion Turbine California 61 2013

Kensico 650 1 Hydro New York 0.8 2012

Kensico 650 2 Hydro New York 0.8 2012

Kensico 650 3 Hydro New York 0.8 2012

Kerckhoff 250 H2 Hydro California 8.6 2013

Kern River Fee A Cogen 52094 GEN1 Combustion Turbine California 3.2 2011

Kern River Fee A Cogen 52094 GEN2 Combustion Turbine California 3.2 2011

Kern River Fee B Cogen 52092 GEN1 Combustion Turbine California 3.2 2011

Kern River Fee C Cogen 52095 GEN1 Combustion Turbine California 3.2 2011

Kern River Fee C Cogen 52095 GEN2 Combustion Turbine California 3.2 2011

Kewaunee 8024 1 Nuclear Wisconsin 566 2013

Kinsleys Landfill 10045 11 Landfill Gas New Jersey 0.5 2014

Kinsleys Landfill 10045 12 Landfill Gas New Jersey 0.5 2014

Kinsleys Landfill 10045 13 Landfill Gas New Jersey 0.5 2014

Kinsleys Landfill 10045 14 Landfill Gas New Jersey 0.5 2014

Kitty Hawk 2757 GT1 Combustion Turbine North Carolina 16 2011

Kitty Hawk 2757 GT2 Combustion Turbine North Carolina 15 2011

KMS Crossroads 50693 DG

- 1 Combustion Turbine New Jersey 0.1 2011

KMS Crossroads 50693 DG

- 3 Combustion Turbine New Jersey 0.1 2011

KMS Crossroads 50693 TG

- 4 Combustion Turbine New Jersey 0.1 2011

Koppers Susquehanna Plant 10731 1 Biomass Pennsylvania 12 2013

Kraft 733 1 Coal Steam Georgia 48 2016

Kraft 733 2 Coal Steam Georgia 52 2016

Kraft 733 3 Coal Steam Georgia 101 2016

Kraft 733 4 O/G Steam Georgia 115 2016

L V Sutton 2713 1 Coal Steam North Carolina 97 2013

L V Sutton 2713 2 Coal Steam North Carolina 104 2013

L V Sutton 2713 3 Coal Steam North Carolina 389 2013

L V Sutton 2713 GT1 Combustion Turbine North Carolina 11 2011

L V Sutton 2713 GTA Combustion Turbine North Carolina 24 2011

## 189 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

L V Sutton 2713 GTB Combustion Turbine North Carolina 26 2011

La Plata 2140 8 Combustion Turbine Missouri 0.9 2012

La Plata 2140 9 Combustion Turbine Missouri 0.9 2012

Lake Creek 3502 D1 Combustion Turbine Texas 2 2009

Lake Creek 3502 D2 Combustion Turbine Texas 2 2009

Lake Creek 3502 D3 Combustion Turbine Texas 2 2009

Lake Gas Recovery 50575 GEN3 Landfill Gas Illinois 2.9 2013

Lamar Plant 508 4 Coal Steam Colorado 40 1989

Lansing 1047 2 Coal Steam Iowa 8.4 2010

Lansing 1047 3 Coal Steam Iowa 21 2013

Lawrence County Station 7948 1 Combustion Turbine Indiana 44 2014

Lawrence County Station 7948 2 Combustion Turbine Indiana 44 2015

Lee 2709 GT1 Combustion Turbine North Carolina 12 2012

Lee 2709 GT2 Combustion Turbine North Carolina 21 2012

Lee 2709 GT3 Combustion Turbine North Carolina 21 2012

Lee 2709 GT4 Combustion Turbine North Carolina 21 2012

Lexington Hickory Street 56066 1 Combustion Turbine North Carolina 1.8 2012

Lilliwaup Falls Generating 50700 4735 Hydro Washington 0.2 2015

Lilliwaup Falls Generating 50700 4736 Hydro Washington 0.2 2015

Lilliwaup Falls Generating 50700 4737 Hydro Washington 0.2 2015

Lilliwaup Falls Generating 50700 4738 Hydro Washington 0.2 2015

Lilliwaup Falls Generating 50700 4739 Hydro Washington 0.2 2015

Lilliwaup Falls Generating 50700 4740 Hydro Washington 0.2 2015

Lilliwaup Falls Generating 50700 4741 Hydro Washington 0.2 2015

Little Company of Mary Hospital 10400 GEN1 Combustion Turbine Illinois 3.2 2012

Little Mountain 6553 1 Combustion Turbine Utah 14 2011

Loveridge Road Power Plant 10368 CB1302 Coal Steam California 18 2012

Low Moor 3799 GT1 Combustion Turbine Virginia 12 2016

Low Moor 3799 GT2 Combustion Turbine Virginia 12 2016

Low Moor 3799 GT3 Combustion Turbine Virginia 12 2016

Low Moor 3799 GT4 Combustion Turbine Virginia 12 2016

Lowell Cogen Plant 10802 GEN1 Combined Cycle Massachusetts 20 2013

Lowell Cogen Plant 10802 GEN2 Combined Cycle Massachusetts 8.5 2013

Macon 2141 1 Combustion Turbine Missouri 4.8 2012

Maiden Finger Street 56065 1 Combustion Turbine North Carolina 1.8 2012

Main Street 2162 1 Combustion Turbine Missouri 12 2010

Marysville 1732 10 Coal Steam Michigan 42 2011

Marysville 1732 11 Coal Steam Michigan 42 2011

Marysville 1732 12 Coal Steam Michigan 42 2011

Marysville 1732 9 Coal Steam Michigan 42 2011

McIntosh 6124 1 Coal Steam Georgia 156.5 2015

## 190 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

McKittrick Cogen 52076 GEN1 Combustion Turbine California 3 2012

McKittrick Cogen 52076 GEN2 Combustion Turbine California 3 2012

McKittrick Cogen 52076 GEN3 Combustion Turbine California 3 2012

McManus 715 1 O/G Steam Georgia 43 2015

McManus 715 2 O/G Steam Georgia 79 2015

McManus 715 IC1 Combustion Turbine Georgia 2 2013

Medicine Bow 692 CLIP Wind Wyoming 2.5 2011

Medway 1474 IC1 Combustion Turbine Maine 2 2014

Medway 1474 IC2 Combustion Turbine Maine 2 2014

Medway 1474 IC3 Combustion Turbine Maine 2 2014

Medway 1474 IC4 Combustion Turbine Maine 2 2014

Meredosia 864 1 Coal Steam Illinois 26 2009

Meredosia 864 2 Coal Steam Illinois 26 2009

Meredosia 864 3 Coal Steam Illinois 26 2009

Meredosia 864 4 Coal Steam Illinois 26 2009

Meredosia 864 5 Coal Steam Illinois 203 2011

Meredosia 864 6 O/G Steam Illinois 166 2011

Miami Fort 2832 6 Coal Steam Ohio 163 2015

Miami Wabash 1006 4 Combustion Turbine Indiana 16 2011

Michoud 1409 1 O/G Steam Louisiana 65 2011

Middle Point Landfill Gas Recovery 56866 1 Landfill Gas Tennessee 1.4 2011

Middle Point Landfill Gas Recovery 56866 2 Landfill Gas Tennessee 1.4 2011

Middle Station 2382 MID1 Combustion Turbine New Jersey 19.1 2015

Middle Station 2382 MID2 Combustion Turbine New Jersey 19.5 2015

Middle Station 2382 MID3 Combustion Turbine New Jersey 36 2015

Miramar 305 MRGT Combustion Turbine California 36 2013

Missouri Avenue 2383 MISB Combustion Turbine New Jersey 20.5 2015

Missouri Avenue 2383 MISC Combustion Turbine New Jersey 20.5 2015

Missouri Avenue 2383 MISD Combustion Turbine New Jersey 20.6 2015

Mitchell 727 3 Coal Steam Georgia 155 2013

Mitchell 3948 2 Coal Steam West Virginia 790 2013

Modern Landfill Production Plant 55142 GEN2 Landfill Gas Pennsylvania 3 2014

Modern Landfill Production Plant 55142 GEN3 Landfill Gas Pennsylvania 3 2014

Modern Landfill Production Plant 55142 GEN4 Landfill Gas Pennsylvania 3 2014

Monroe 1448 10 O/G Steam Louisiana 22 2011

Monroe 1448 11 O/G Steam Louisiana 33 2011

Monroe 1448 12 O/G Steam Louisiana 71 2011

Montauk 2515 2 Combustion Turbine New York 2 2013

Montauk 2515 3 Combustion Turbine New York 2 2013

Montauk 2515 4 Combustion Turbine New York 1.9 2013

Montgomery 8025 1 Combustion Turbine Minnesota 20.6 2012

## 191 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

Monticello 6147 1 Coal Steam Texas 565 2013

Monticello 6147 2 Coal Steam Texas 565 2013

Montrose 2080 1 Coal Steam Missouri 169 2016

Moorhead 1995 6 Combustion Turbine Minnesota 5.9 2011

Morehead 2711 GT1 Combustion Turbine North Carolina 12 2012

Morgan City 1449 1 O/G Steam Louisiana 5.8 2015

Morgan City 1449 2 O/G Steam Louisiana 5.8 2015

Morgan Creek 3492 5 O/G Steam Texas 175 2005

Morgan Creek 3492 6 O/G Steam Texas 511 2005

Morris Genco LLC 55774 MO1 Landfill Gas Illinois 1.3 2011

Morris Genco LLC 55774 MO2 Landfill Gas Illinois 1.3 2011

Morris Genco LLC 55774 MO3 Landfill Gas Illinois 1.3 2011

Morris Sheppard 3557 1 Hydro Texas 12 2013

Morris Sheppard 3557 2 Hydro Texas 12 2013

Mount Tom 1606 1 Coal Steam Massachusetts 144 2014

Mt Storm 3954 JF1 Combustion Turbine West Virginia 11 2016

Mullen 2280 3 Combustion Turbine Nebraska 0.3 2011

Mullen 2280 4 Combustion Turbine Nebraska 0.6 2012

Muskingum River 2872 1 Coal Steam Ohio 190 2015

Muskingum River 2872 2 Coal Steam Ohio 190 2015

Muskingum River 2872 3 Coal Steam Ohio 205 2015

Muskingum River 2872 4 Coal Steam Ohio 205 2015

Natchez 2052 1 O/G Steam Mississippi 73 2011

National Grid Glenwood Energy Center 2514 40 O/G Steam New York 116 2012

National Grid Glenwood Energy Center 2514 50 O/G Steam New York 113 2012

Neil Simpson 4150 5 Coal Steam Wyoming 14.6 2014

Nelson Dewey 4054 1 Coal Steam Wisconsin 115 2016

Nelson Dewey 4054 2 Coal Steam Wisconsin 111 2016

Nelson Plant Generators 54245 EXI1 Combustion Turbine Arizona 1.1 2011

Nelson Plant Generators 54245 EXI2 Combustion Turbine Arizona 1.1 2010

Neosho 1243 7 O/G Steam Kansas 67 2012

New Albany Energy Facility 55080 1 Combustion Turbine Mississippi 60 2015

New Albany Energy Facility 55080 2 Combustion Turbine Mississippi 60 2015

New Albany Energy Facility 55080 3 Combustion Turbine Mississippi 60 2015

New Albany Energy Facility 55080 4 Combustion Turbine Mississippi 60 2015

New Albany Energy Facility 55080 5 Combustion Turbine Mississippi 60 2015

New Albany Energy Facility 55080 6 Combustion Turbine Mississippi 60 2015

New Badger 4120 1 Hydro Wisconsin 1.8 2012

New Badger 4120 2 Hydro Wisconsin 1.8 2012

New Castle Plant 3138 3 Coal Steam Pennsylvania 93 2015

New Castle Plant 3138 4 Coal Steam Pennsylvania 95 2015

## 192 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

New Castle Plant 3138 5 Coal Steam Pennsylvania 132 2015

New Castle Plant 3138 EMDA Combustion Turbine Pennsylvania 3 2015

New Castle Plant 3138 EMDB Combustion Turbine Pennsylvania 3 2015

New Hanover County WASTEC 50271 1A Municipal Solid

Waste North Carolina 1.2 2001

Newby Island II 10389 1 Landfill Gas California 1 2012

Newby Island II 10389 2 Landfill Gas California 1 2012

Newby Island II 10389 3 Landfill Gas California 1 2012

Nichols Road Power Plant 10371 CB1302 Coal Steam California 17.8 2012

Niles 2861 1 Coal Steam Ohio 108 2012

Niles 2861 2 Coal Steam Ohio 108 2012

Nine Mile 3869 1 Hydro Washington 8.9 2015

Nine Mile Point 1403 1 O/G Steam Louisiana 50 2011

Nine Mile Point 1403 2 O/G Steam Louisiana 107 2011

Nine Mile Point 1403 6 Combined Cycle Louisiana 0 2015

North Branch 7537 A Coal Steam West Virginia 37 2014

North Branch 7537 B Coal Steam West Virginia 37 2014

Northwind Energy 10738 GEN1 Wind California 12.1 2012

Norton 1310 1 Combustion Turbine Kansas 0.9 2011

Norton 1310 2 Combustion Turbine Kansas 1.3 2011

Norton 1310 3 Combustion Turbine Kansas 2.4 2011

Norton 1310 4 Combustion Turbine Kansas 3.1 2011

Norton 1310 5 Combustion Turbine Kansas 2.2 2011

NRG Norwalk Harbor 548 1 O/G Steam Connecticut 162 2013

NRG Norwalk Harbor 548 10 Combustion Turbine Connecticut 11.9 2013

NRG Norwalk Harbor 548 2 O/G Steam Connecticut 168 2013

Nueces Bay 3441 7 Combined Cycle Texas 368 2005

O H Hutchings 2848 H

- 1 Coal Steam Ohio 58 2015

O H Hutchings 2848 H

- 2 Coal Steam Ohio 55 2015

O H Hutchings 2848 H

- 3 Coal Steam Ohio 63 2015

O H Hutchings 2848 H

- 4 Coal Steam Ohio 63 2013

O H Hutchings 2848 H

- 5 Coal Steam Ohio 63 2015

O H Hutchings 2848 H

- 6 Coal Steam Ohio 63 2015

Oakely 1311 1 Combustion Turbine Kansas 1.2 2012

Oakely 1311 2 Combustion Turbine Kansas 0.3 2012

Oakely 1311 4 Combustion Turbine Kansas 0.8 2012

Oakely 1311 6 Combustion Turbine Kansas 3.2 2012

Oakland Dam Hydroelectric 10433 1 Hydro Pennsylvania 0.5 2015

Oakland Dam Hydroelectric 10433 2 Hydro Pennsylvania 0.5 2015

Odessa 2148 2 Combustion Turbine Missouri 0.2 2011

Odessa 2148 5 Combustion Turbine Missouri 1 2008

Oglesby 894 1 Combustion Turbine Illinois 13.5 2013

## 193 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

Oglesby 894 2 Combustion Turbine Illinois 13.5 2013

Oglesby 894 3 Combustion Turbine Illinois 13.5 2013

Oglesby 894 4 Combustion Turbine Illinois 13.5 2013

Old Badger 4121 3 Hydro Wisconsin 1 2012

Old Badger 4121 4 Hydro Wisconsin 1 2012

Oneida Casino 7602 1 Combustion Turbine Wisconsin 1.8 2011

Oneida Casino 7602 2 Combustion Turbine Wisconsin 1.8 2011

Onondaga Energy Partners LP 50346 ON1 Landfill Gas New York 0.6 2010

Ormesa I 50766 OE1 Geothermal California 0.7 2003

Ormesa I 50766 OE10 Geothermal California 0.7 2003

Ormesa I 50766 OE13 Geothermal California 0.7 2003

Ormesa I 50766 OE16 Geothermal California 0.7 2003

Ormesa I 50766 OE2 Geothermal California 0.7 2003

Ormesa I 50766 OE23 Geothermal California 0.9 2008

Ormesa I 50766 OE26 Geothermal California 0.9 2012

Ormesa I 50766 OE27 Geothermal California 0.9 2003

Ormesa I 50766 OE28 Geothermal California 0.9 2003

Ormesa I 50766 OE3 Geothermal California 0.9 2003

Ormesa I 50766 OE4 Geothermal California 0.7 2003

Ormesa I 50766 OE5 Geothermal California 1.1 2003

Ormesa I 50766 OE6 Geothermal California 1.1 2003

Ormesa I 50766 OE7 Geothermal California 0.7 2003

Ormesa I 50766 OE8 Geothermal California 0.7 2003

Ormesa I 50766 OE9 Geothermal California 0.7 2003

Ormesa IE 50764 OE10 Geothermal California 0.6 2009

Ormesa IE 50764 OE11 Geothermal California 1 2009

Ormesa IE 50764 OE12 Geothermal California 0.6 2009

Ormesa IE 50764 OEC1 Geothermal California 1 2009

Ormesa IE 50764 OEC2 Geothermal California 0.6 2009

Ormesa IE 50764 OEC3 Geothermal California 1 2009

Ormesa IE 50764 OEC4 Geothermal California 0.6 2009

Ormesa IE 50764 OEC5 Geothermal California 1 2009

Ormesa IE 50764 OEC6 Geothermal California 0.6 2009

Ormesa IE 50764 OEC7 Geothermal California 1 2009

Ormesa IE 50764 OEC8 Geothermal California 0.6 2009

Ormesa IE 50764 OEC9 Geothermal California 1 2009

Ormesa IH 50762 OE11 Geothermal California 1 2016

Ormesa II 54724 OE11 Geothermal California 0.9 2007

Ormesa II 54724 OE12 Geothermal California 0.9 2007

Ormesa II 54724 OE13 Geothermal California 0.9 2007

Ormesa II 54724 OE21 Geothermal California 0.9 2007

## 194 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

Ormesa II 54724 OE22 Geothermal California 0.9 2007

Ormesa II 54724 OE23 Geothermal California 0.9 2007

Ormesa II 54724 OE24 Geothermal California 0.9 2007

Ormesa II 54724 OE25 Geothermal California 0.9 2007

Ormesa II 54724 OE26 Geothermal California 0.9 2007

Ormesa II 54724 OE27 Geothermal California 0.9 2007

Ormesa II 54724 OEC1 Geothermal California 0.9 2007

Ormesa II 54724 OEC2 Geothermal California 0.9 2007

Ormesa II 54724 OEC3 Geothermal California 0.9 2007

Ormesa II 54724 OEC4 Geothermal California 0.9 2007

Ormesa II 54724 OEC5 Geothermal California 0.9 2007

Ormesa II 54724 OEC6 Geothermal California 0.9 2007

Ormesa II 54724 OEC7 Geothermal California 0.9 2007

Ormesa II 54724 OEC8 Geothermal California 0.9 2007

Ormesa II 54724 OEC9 Geothermal California 0.9 2007

Osage 4151 1 Coal Steam Wyoming 10.1 2010

Osage 4151 2 Coal Steam Wyoming 10.1 2010

Osage 4151 3 Coal Steam Wyoming 10.1 2010

Osceola 172 10 Combustion Turbine Arkansas 1.6 2012

Osceola 172 11 Combustion Turbine Arkansas 1.6 2012

Osceola 172 12 Combustion Turbine Arkansas 1.6 2012

Owatonna 2003 6 O/G Steam Minnesota 20.6 2011

Owensville 2149 3A Combustion Turbine Missouri 1.8 2011

Owensville 2149 4A Combustion Turbine Missouri 1.3 2011

Owensville 2149 4B Combustion Turbine Missouri 1.8 2011

Owensville 2149 5 Combustion Turbine Missouri 1.3 2011

Owensville 2149 6 Combustion Turbine Missouri 1.8 2011

Owensville 2149 6A Combustion Turbine Missouri 1.8 2011

Palos Verdes Gas to Energy 10473 B501 Landfill Gas California 1.2 2011

Pearl Station 6238 1A Coal Steam Illinois 22.2 2012

Pella 1175 6 Coal Steam Iowa 11.5 2014

Pella 1175 7 Coal Steam Iowa 11.5 2012

Pella 1175 8 Coal Steam Iowa 11.5 2012

Permian Basin 3494 5 O/G Steam Texas 115 2011

Peru 955 10 Combustion Turbine Illinois 2 2011

Peru 955 3 Combustion Turbine Illinois 1.8 2010

Peru 955 7 Combustion Turbine Illinois 1.8 2010

Peru 955 8 Combustion Turbine Illinois 2 2010

Peru 955 9 Combustion Turbine Illinois 2 2010

Peru 955 IC1 Combustion Turbine Illinois 6 2011

Peru 955 IC2 Combustion Turbine Illinois 1.8 2010

## 195 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

Peru 955 IC3 Combustion Turbine Illinois 1.8 2011

Philip Sporn 3938 11 Coal Steam West Virginia 145 2015

Philip Sporn 3938 21 Coal Steam West Virginia 145 2015

Philip Sporn 3938 31 Coal Steam West Virginia 145 2015

Philip Sporn 3938 41 Coal Steam West Virginia 145 2015

Philip Sporn 3938 51 Coal Steam West Virginia 440 2012

Picway 2843 9 Coal Steam Ohio 95 2015

Piney Creek Project 54144 BRBR1 Coal Steam Pennsylvania 32 2013

Pittsfield 6237 1 Combustion Turbine Illinois 1 2011

Pittsfield 6237 2 Combustion Turbine Illinois 1 2011

Pittsfield 6237 3 Combustion Turbine Illinois 1 2011

Pittsfield 6237 4 Combustion Turbine Illinois 2.7 2011

Pittsfield 6237 5 Combustion Turbine Illinois 2.7 2011

Plant X 3485 113B O/G Steam Texas 93 2014

Plant X 3485 114B O/G Steam Texas 200 2014

Port Everglades 617 PPE1 O/G Steam Florida 213 2013

Port Everglades 617 PPE2 O/G Steam Florida 213 2013

Port Everglades 617 PPE3 O/G Steam Florida 387 2013

Port Everglades 617 PPE4 O/G Steam Florida 392 2013

Porterdale Hydro 50242 TB

- 1 Hydro Georgia 0.7 2015

Porterdale Hydro 50242 TB

- 2 Hydro Georgia 0.7 2015

Portland 3113 1 Coal Steam Pennsylvania 158 2014

Portland 3113 2 Coal Steam Pennsylvania 243 2014

Possum Point 3804 GT1 Combustion Turbine Virginia 12 2015

Possum Point 3804 GT2 Combustion Turbine Virginia 12 2015

Possum Point 3804 GT3 Combustion Turbine Virginia 12 2015

Possum Point 3804 GT4 Combustion Turbine Virginia 12 2015

Possum Point 3804 GT5 Combustion Turbine Virginia 12 2015

Possum Point 3804 GT6 Combustion Turbine Virginia 12 2015

Powerdale 3031 1 Hydro Oregon 6 2007

PPL Veazie Hydro Station 1479 VZ01 Hydro Maine 0.7 2013

PPL Veazie Hydro Station 1479 VZ02 Hydro Maine 0.3 2013

PPL Veazie Hydro Station 1479 VZ03 Hydro Maine 0.3 2013

PPL Veazie Hydro Station 1479 VZ04 Hydro Maine 0.3 2013

PPL Veazie Hydro Station 1479 VZ05 Hydro Maine 0.3 2013

PPL Veazie Hydro Station 1479 VZ06 Hydro Maine 0.3 2013

PPL Veazie Hydro Station 1479 VZ07 Hydro Maine 0.3 2013

PPL Veazie Hydro Station 1479 VZ08 Hydro Maine 0.3 2013

PPL Veazie Hydro Station 1479 VZ09 Hydro Maine 0.3 2013

PPL Veazie Hydro Station 1479 VZ10 Hydro Maine 0.3 2013

PPL Veazie Hydro Station 1479 VZ11 Hydro Maine 0.3 2013

## 196 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

PPL Veazie Hydro Station 1479 VZ12 Hydro Maine 0.3 2013

PPL Veazie Hydro Station 1479 VZ13 Hydro Maine 0.3 2013

PPL Veazie Hydro Station 1479 VZ14 Hydro Maine 0.3 2013

PPL Veazie Hydro Station 1479 VZ15 Hydro Maine 0.5 2013

PPL Veazie Hydro Station 1479 VZ16 Hydro Maine 1.4 2013

PPL Veazie Hydro Station 1479 VZ17 Hydro Maine 1.4 2013

Prairie Creek 1073 2 Coal Steam Iowa 2.1 2010

Prairie River 378 1 Hydro Minnesota 0.3 2015

Prairie River 378 2 Hydro Minnesota 0.3 2015

Pratt 1317 4 O/G Steam Kansas 5.8 2012

PSEG Burlington Generating Station 2399 111 Combustion Turbine New Jersey 46.3 2015

PSEG Burlington Generating Station 2399 112 Combustion Turbine New Jersey 46 2015

PSEG Burlington Generating Station 2399 113 Combustion Turbine New Jersey 46.2 2015

PSEG Burlington Generating Station 2399 114 Combustion Turbine New Jersey 46 2015

PSEG Burlington Generating Station 2399 91 Combustion Turbine New Jersey 48.8 2015

PSEG Burlington Generating Station 2399 92 Combustion Turbine New Jersey 47 2015

PSEG Burlington Generating Station 2399 93 Combustion Turbine New Jersey 48 2015

PSEG Burlington Generating Station 2399 94 Combustion Turbine New Jersey 47 2015

PSEG Edison Generating Station 2400 11 Combustion Turbine New Jersey 44.1 2015

PSEG Edison Generating Station 2400 12 Combustion Turbine New Jersey 42.8 2015

PSEG Edison Generating Station 2400 13 Combustion Turbine New Jersey 43.6 2015

PSEG Edison Generating Station 2400 14 Combustion Turbine New Jersey 43.1 2015

PSEG Edison Generating Station 2400 21 Combustion Turbine New Jersey 43 2015

PSEG Edison Generating Station 2400 22 Combustion Turbine New Jersey 44 2015

PSEG Edison Generating Station 2400 23 Combustion Turbine New Jersey 42.8 2015

PSEG Edison Generating Station 2400 24 Combustion Turbine New Jersey 43.9 2015

PSEG Edison Generating Station 2400 31 Combustion Turbine New Jersey 42.6 2015

PSEG Edison Generating Station 2400 32 Combustion Turbine New Jersey 43.7 2015

PSEG Edison Generating Station 2400 33 Combustion Turbine New Jersey 43.1 2015

PSEG Edison Generating Station 2400 34 Combustion Turbine New Jersey 43.1 2015

PSEG Essex Generating Station 2401 101 Combustion Turbine New Jersey 44 2015

PSEG Essex Generating Station 2401 102 Combustion Turbine New Jersey 43.6 2015

PSEG Essex Generating Station 2401 103 Combustion Turbine New Jersey 43.6 2015

PSEG Essex Generating Station 2401 104 Combustion Turbine New Jersey 44.6 2015

PSEG Essex Generating Station 2401 111 Combustion Turbine New Jersey 46.1 2015

PSEG Essex Generating Station 2401 112 Combustion Turbine New Jersey 47.6 2015

PSEG Essex Generating Station 2401 113 Combustion Turbine New Jersey 46.1 2015

PSEG Essex Generating Station 2401 114 Combustion Turbine New Jersey 46.1 2015

PSEG Essex Generating Station 2401 121 Combustion Turbine New Jersey 46.6 2015

PSEG Essex Generating Station 2401 122 Combustion Turbine New Jersey 46.8 2015

PSEG Essex Generating Station 2401 123 Combustion Turbine New Jersey 47.6 2015

## 197 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

PSEG Essex Generating Station 2401 124 Combustion Turbine New Jersey 46.6 2015

PSEG Sewaren Generating Station 2411 1 O/G Steam New Jersey 105 2015

PSEG Sewaren Generating Station 2411 2 O/G Steam New Jersey 108.3 2015

PSEG Sewaren Generating Station 2411 3 O/G Steam New Jersey 107.9 2015

PSEG Sewaren Generating Station 2411 4 O/G Steam New Jersey 121.8 2015

Pueblo 460 41 O/G Steam Colorado 9 2013

Pueblo 460 49 O/G Steam Colorado 18.8 2013

Pulliam 4072 5 Coal Steam Wisconsin 52 2015

Pulliam 4072 6 Coal Steam Wisconsin 71 2015

R Gallagher 1008 1 Coal Steam Indiana 140 2012

R Gallagher 1008 3 Coal Steam Indiana 140 2012

Rabun Gap Cogen Facility 50201 WB1 Biomass Georgia 17 2010

Rantoul 958 5 Combustion Turbine Illinois 0.7 2012

Ravenswood 2500 GT8 Combustion Turbine New York 20 2015

Reid Gardner 2324 1 Coal Steam Nevada 100 2014

Reid Gardner 2324 2 Coal Steam Nevada 100 2014

Reid Gardner 2324 3 Coal Steam Nevada 98 2014

Renaissance Power LLC 55402 CT1 Combustion Turbine Michigan 165 2015

Renaissance Power LLC 55402 CT2 Combustion Turbine Michigan 165 2015

Renaissance Power LLC 55402 CT3 Combustion Turbine Michigan 165 2015

Renaissance Power LLC 55402 CT4 Combustion Turbine Michigan 165 2015

Rex Brown 2053 1A O/G Steam Mississippi 7.5 2011

Rio Grande 2444 7 O/G Steam New Mexico 46 2014

Rio Pinar 637 P1 Combustion Turbine Florida 12 2016

Riverside 1559 4 O/G Steam Maryland 74 2015

Riverside 1559 GT6 Combustion Turbine Maryland 115 2014

Riverton 1239 39 O/G Steam Kansas 38 2016

Riverton 1239 40 O/G Steam Kansas 54 2016

Riverton 1239 9 Combustion Turbine Kansas 12 2014

Riveside Resource Recovery LLC 55767 RO1 Landfill Gas Illinois 0.9 2012

Riviera 619 PRV3 O/G Steam Florida 277 2011

Riviera 619 PRV4 O/G Steam Florida 288 2011

Robert E Ritchie 173 1 O/G Steam Arkansas 300 2013

Rochester 3 2640 13 Combustion Turbine New York 14.4 2011

Rochester 5 2641 2 Hydro New York 12.9 2015

Rochester 5 2641 HY1 Hydro New York 12.9 2015

Rochester 5 2641 HY3 Hydro New York 18 2015

Rochester 9 2644 2 Combustion Turbine New York 14 2014

Rocky River 3305 IC1 Combustion Turbine South Carolina 1.1 2013

S D Warren Westbrook 50447 20 O/G Steam Maine 10.1 2009

Sabetha Power Plant 1320 4 Combustion Turbine Kansas 0.7 2012

## 198 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

Sabetha Power Plant 1320 8 Combustion Turbine Kansas 2.1 2012

Saguaro 118 1 O/G Steam Arizona 110 2013

Saguaro 118 2 O/G Steam Arizona 100 2013

Saguaro 118 PV1 Solar Thermal Arizona 1 2013

San Francisquito 2 6480 1 Hydro California 14.5 2015

San Gorgonio Windplant WPP1993 54454 GEN3 Wind California 34 2011

San Onofre Nuclear Generating Station 360 2 Nuclear California 1094 2013

San Onofre Nuclear Generating Station 360 3 Nuclear California 1080 2013

Sanford 620 PSN3 O/G Steam Florida 138 2012

Savannah River Site Biomass Cogeneration 57138 HRSG1 Biomass South Carolina 9 2011

Savannah River Site Biomass Cogeneration 57138 HRSG2 Biomass South Carolina 9 2011

SBD 9801 Aegon Martha's Way 56072 1 Combustion Turbine Iowa 1 2012

Scattergood 404 3 O/G Steam California 445 2016

Scholz 642 1 Coal Steam Florida 46 2015

Scholz 642 2 Coal Steam Florida 46 2015

Schuylkill Generating Station 3169 1 O/G Steam Pennsylvania 166 2012

Schuylkill Generating Station 3169 IC1 Combustion Turbine Pennsylvania 2.7 2013

Seaford 601 1 Combustion Turbine Delaware 1.3 2011

Seaford 601 2 Combustion Turbine Delaware 1.3 2011

Seaford 601 3 Combustion Turbine Delaware 1.1 2011

Seaford 601 6 Combustion Turbine Delaware 2 2011

Seaford 601 7 Combustion Turbine Delaware 1.1 2011

Seaford Delaware Plant 10793 BLR5 O/G Steam Delaware 9 2009

Seaford Delaware Plant 10793 GEN1 O/G Steam Delaware 9 2009

Shawville 3131 1 Coal Steam Pennsylvania 122 2015

Shawville 3131 2 Coal Steam Pennsylvania 125 2015

Shawville 3131 3 Coal Steam Pennsylvania 175 2015

Shawville 3131 4 Coal Steam Pennsylvania 175 2015

Shelby Municipal Light Plant 2943 1 Coal Steam Ohio 12 2012

Shelby Municipal Light Plant 2943 2 Coal Steam Ohio 12 2012

Shelby Municipal Light Plant 2943 3 Coal Steam Ohio 5 2012

Sierra Pacific Loyalton Facility 50111 BLR1 Biomass California 11.8 2010

Silver Lake 2008 1 Coal Steam Minnesota 9.6 2016

Silver Lake 2008 2 Coal Steam Minnesota 14.3 2016

Silver Lake 2008 3 Coal Steam Minnesota 23.5 2016

Silver Lake 2008 4 Coal Steam Minnesota 57 2016

Small Hydro of Texas 55000 1 Hydro Texas 0.4 2015

Small Hydro of Texas 55000 2 Hydro Texas 0.4 2015

Small Hydro of Texas 55000 3 Hydro Texas 0.4 2015

Smart Papers LLC 50247 B010 Coal Steam Ohio 26 2012

Smart Papers LLC 50247 B020 Coal Steam Ohio 15.1 2012

## 199 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

Smart Papers LLC 50247 B022 Coal Steam Ohio 4.5 2012

Solar Photovoltaic Project #01 56976 S1A Solar PV California 0.5 2011

Solar Photovoltaic Project #01 56976 S1B Solar PV California 0.5 2011

Solar Photovoltaic Project #01 56976 S1C Solar PV California 0.5 2011

Solar Photovoltaic Project #01 56976 S1D Solar PV California 0.5 2011

Somerset Station 1613 6 Coal Steam Massachusetts 109 2012

South Barrington Electric 55594 1 Landfill Gas Illinois 0.8 2012

South Barrington Electric 55594 2 Landfill Gas Illinois 0.8 2012

Stafford 1325 1 Combustion Turbine Kansas 0.9 2011

Stallings 895 1 Combustion Turbine Illinois 20.5 2013

Stallings 895 2 Combustion Turbine Illinois 20.5 2013

Stallings 895 3 Combustion Turbine Illinois 20.5 2013

Stallings 895 4 Combustion Turbine Illinois 20.5 2013

State St Generating 7970 1 Combustion Turbine Michigan 1.8 2012

State St Generating 7970 2 Combustion Turbine Michigan 1.8 2012

State St Generating 7970 3 Combustion Turbine Michigan 1.8 2012

State St Generating 7970 4 Combustion Turbine Michigan 1.8 2012

State St Generating 7970 5 Combustion Turbine Michigan 1.8 2012

State St Generating 7970 6 Combustion Turbine Michigan 1.8 2012

State St Generating 7970 7 Combustion Turbine Michigan 1.8 2012

State St Generating 7970 8 Combustion Turbine Michigan 1.8 2012

State St Generating 7970 9 Combustion Turbine Michigan 1.8 2012

Steamboat 1 50763 OE11 Geothermal Nevada 0.9 2015

Steamboat 1 50763 OE12 Geothermal Nevada 0.9 2015

Steamboat 1 50763 OE13 Geothermal Nevada 0.9 2015

Steamboat 1 50763 OE14 Geothermal Nevada 0.9 2015

Steamboat 1 50763 OE21 Geothermal Nevada 0.9 2015

Steamboat 1 50763 OE22 Geothermal Nevada 0.9 2015

Steamboat 1 50763 OE23 Geothermal Nevada 0.9 2015

Steamboat 1A Power Plant 52138 DE32 Geothermal Nevada 0.9 2015

Sterlington 1404 10 O/G Steam Louisiana 212 2012

Sunbury Generation LP 3152 1A Coal Steam Pennsylvania 41 2014

Sunbury Generation LP 3152 1B Coal Steam Pennsylvania 41 2014

Sunbury Generation LP 3152 2A Coal Steam Pennsylvania 41 2014

Sunbury Generation LP 3152 2B Coal Steam Pennsylvania 41 2014

Sunbury Generation LP 3152 3 Coal Steam Pennsylvania 90 2014

Sunbury Generation LP 3152 4 Coal Steam Pennsylvania 128 2014

Sunrise 2326 1 O/G Steam Nevada 80 2011

Sunrise 2326 2 Combustion Turbine Nevada 69 2011

Sutherland 2306 2 Combustion Turbine Nebraska 0.9 2009

Swift 2 6265 21 Hydro Washington 34 2015

## 200 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

Taconite Harbor Energy Center 10075 3 Coal Steam Minnesota 76 2015

Tangier 6390 3 Combustion Turbine Virginia 0.6 2015

Tangier 6390 4 Combustion Turbine Virginia 0.8 2015

Tanners Creek 988 U1 Coal Steam Indiana 145 2015

Tanners Creek 988 U2 Coal Steam Indiana 145 2015

Tanners Creek 988 U3 Coal Steam Indiana 200 2015

Teche 1400 2 O/G Steam Louisiana 33 2011

Tecumseh Energy Center 1252 1 Combustion Turbine Kansas 18 2012

Tecumseh Energy Center 1252 2 Combustion Turbine Kansas 19 2012

Thermo No 1 57353 1 Geothermal Utah 7.6 2013

Thomas C Ferguson 4937 1 O/G Steam Texas 420 2013

Thousand Springs 820 1 Hydro Idaho 0.8 2015

Thousand Springs 820 2 Hydro Idaho 0.8 2015

Tillotson Rubber 50095 HG1 Hydro New

Hampshire 0.1 2011

Tillotson Rubber 50095 IC1 Combustion Turbine New

Hampshire 0.4 2012

Tillotson Rubber 50095 IC2 Combustion Turbine New

Hampshire 0.6 2012

Tillotson Rubber 50095 TG2 Biomass New

Hampshire 0.6 2012

Tillotson Rubber 50095 TGI Biomass New

Hampshire 0.7 2012

Titus 3115 1 Coal Steam Pennsylvania 81 2013

Titus 3115 2 Coal Steam Pennsylvania 81 2013

Titus 3115 3 Coal Steam Pennsylvania 81 2013

TMC LLC 10347 GEN1 Biomass Florida 7.5 2012

Tracy 2336 1 O/G Steam Nevada 53 2013

Tracy 2336 2 O/G Steam Nevada 83 2016

Tracy 2336 GT1 Combustion Turbine Nevada 10 2010

Tracy 2336 GT2 Combustion Turbine Nevada 10 2010

Tradinghouse 3506 1 O/G Steam Texas 565 2010

Tradinghouse 3506 2 O/G Steam Texas 818 2008

Trenton Diesel 2163 4 Combustion Turbine Missouri 0.9 2011

Trenton Diesel 2163 5 Combustion Turbine Missouri 1 2011

Trigen Syracuse Energy 50651 2 Coal Steam New York 24.6 2013

Trigen Syracuse Energy 50651 3 Coal Steam New York 24.6 2013

Trigen Syracuse Energy 50651 4 Coal Steam New York 12.3 2013

Trigen Syracuse Energy 50651 5 Coal Steam New York 12.3 2013

Tulsa 2965 1403 O/G Steam Oklahoma 65 2012

Turkey Point 621 PTP2 O/G Steam Florida 392 2013

Two Elk Generating Station 55360 GEN1 Coal Steam Wyoming 275 2016

Two Harbors 2016 3 Combustion Turbine Minnesota 1.9 2012

TXU Sweetwater Generating Plant 50615 GT01 Combined Cycle Texas 41 2009

TXU Sweetwater Generating Plant 50615 GT02 Combined Cycle Texas 86 2009

TXU Sweetwater Generating Plant 50615 GT03 Combined Cycle Texas 86 2009

## 201 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

Ty Cooke 3602 GT1 Combustion Turbine Texas 11 2012

Tyrone 1361 5 Coal Steam Kentucky 71 2013

Union Carbide Seadrift Cogen 50150 IGT Combined Cycle Texas 12 2015

United Cogen 50104 G

- 1 Combined Cycle California 22 2012

United Cogen 50104 G

- 2 Combined Cycle California 7 2012

Upper Androscoggin 54202 2 Hydro Maine 0.5 2015

Valley Road 6530 1 Combustion Turbine Nevada 2 2011

Valley Road 6530 2 Combustion Turbine Nevada 2 2011

Valley Road 6530 3 Combustion Turbine Nevada 2 2011

Venice 913 GT1 Combustion Turbine Illinois 26 2012

Vermilion 897 1 Coal Steam Illinois 62 2012

Vermilion 897 2 Coal Steam Illinois 99 2012

Vermilion 897 3 Combustion Turbine Illinois 10 2011

Vermont Yankee 3751 1 Nuclear Vermont 620.3 2014

Viaduct 2096 1 Combustion Turbine Missouri 26 2011

Victoria 3443 5 Combined Cycle Texas 125 2005

Viking Energy of Northumberland 50771 B1 Biomass Pennsylvania 16.2 2012

W N Clark 462 55 Coal Steam Colorado 17.6 2013

W N Clark 462 59 Coal Steam Colorado 24.9 2013

Walter C Beckjord 2830 1 Coal Steam Ohio 94 2015

Walter C Beckjord 2830 2 Coal Steam Ohio 94 2013

Walter C Beckjord 2830 3 Coal Steam Ohio 128 2013

Walter C Beckjord 2830 4 Coal Steam Ohio 150 2014

Walter C Beckjord 2830 5 Coal Steam Ohio 238 2014

Walter C Beckjord 2830 6 Coal Steam Ohio 414 2015

Walter C Beckjord 2830 GT1 Combustion Turbine Ohio 47 2014

Walter C Beckjord 2830 GT2 Combustion Turbine Ohio 47 2014

Walter C Beckjord 2830 GT3 Combustion Turbine Ohio 47 2014

Walter C Beckjord 2830 GT4 Combustion Turbine Ohio 47 2014

Wanapum 3888 1 Hydro Washington 97 2012

Wanapum 3888 10 Hydro Washington 112 2014

Wanapum 3888 2 Hydro Washington 97 2012

Wanapum 3888 5 Hydro Washington 97 2011

Wanapum 3888 7 Hydro Washington 115 2010

Wanapum 3888 8 Hydro Washington 112 2013

Ware Energy 50419 GEN1 Biomass Massachusetts 8.7 2012

Washington Parish Energy Center 55486 CTG1 Combined Cycle Louisiana 172 2016

Washington Parish Energy Center 55486 CTG2 Combined Cycle Louisiana 172 2016

Washington Parish Energy Center 55486 ST1 Combined Cycle Louisiana 215 2016

Water Filter Plant #2 55534 3516 Combustion Turbine North Carolina 1.3 2013

Watts Bar Fossil 3419 A Coal Steam Tennessee 56 1985

## 202 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

Watts Bar Fossil 3419 B Coal Steam Tennessee 56 1985

Watts Bar Fossil 3419 C Coal Steam Tennessee 56 1985

Watts Bar Fossil 3419 D Coal Steam Tennessee 56 1985

Webbers Falls 2987 3 Hydro Oklahoma 23 2015

Welsh 6139 2 Coal Steam Texas 528 2014

Werner 2385 GT1 Combustion Turbine New Jersey 53 2015

Werner 2385 GT2 Combustion Turbine New Jersey 53 2015

Werner 2385 GT3 Combustion Turbine New Jersey 53 2015

Werner 2385 GT4 Combustion Turbine New Jersey 53 2015

West Liberty 1200 1 Combustion Turbine Iowa 0.7 2011

Western Renewable Energy 56358 1 Biomass Arizona 2.5 2015

Weston 4078 1 Coal Steam Wisconsin 58 2015

Wilbur East Power Plant 10370 CB1302 Coal Steam California 18.1 2012

Wilbur West Power Plant 10369 CB1302 Coal Steam California 18.2 2012

Will County 884 3 Coal Steam Illinois 251 2015

Williston 2791 2 Combustion Turbine North Dakota 4.7 2012

Williston 2791 3 Combustion Turbine North Dakota 4.9 2012

Wilson 6258 IC1 Combustion Turbine Georgia 2.5 2013

Winnebago County Landfill Gas 50936 EG1 Landfill Gas Wisconsin 0.9 2014

Winnebago County Landfill Gas 50936 EG2 Landfill Gas Wisconsin 0.9 2014

Winnebago County Landfill Gas 50936 EG3 Landfill Gas Wisconsin 0.9 2014

Winnebago County Landfill Gas 50936 EG4 Landfill Gas Wisconsin 1 2014

Winnebago County Landfill Gas 50936 EG5 Landfill Gas Wisconsin 1.4 2014

Winnemucca 6533 1 Combustion Turbine Nevada 15 2011

Winsor Dam Power Station 10826 WINS Hydro Massachusetts 0.6 1991

Wisconsin Rapids 3974 6 Hydro Wisconsin 0.3 2015

Wisconsin Rapids 3974 8 Hydro Wisconsin 0.3 2015

Wiscoy 170 2646 1 Hydro New York 0.6 2015

Wiscoy 170 2646 2 Hydro New York 0.4 2015

Wood River 898 1 O/G Steam Illinois 39 2012

Wood River 898 2 O/G Steam Illinois 39 2012

Wood River 898 3 O/G Steam Illinois 39 2012

Woodward 2958 GT1 Combustion Turbine Oklahoma 9.5 2012

Worcester Energy 10165 1 Biomass Maine 5.7 2015

Worcester Energy 10165 2 Biomass Maine 5.7 2015

Worcester Energy 10165 3 Biomass Maine 5.7 2015

Wythe Park Power Petersburg Plant 54045 1 Fossil Waste Virginia 3 2013

Yates 728 4 Coal Steam Georgia 133 2015

Yates 728 5 Coal Steam Georgia 135 2015

Yates 728 Y1BR Coal Steam Georgia 97 2015

Yates 728 Y2BR Coal Steam Georgia 103 2015

## 203 Plant Name ORIS

Unit ID Plant Type State Name Capacity Retirement

Plant (MW) Year

Code

Yates 728 Y3BR Coal Steam Georgia 111 2015

Yorktown 3809 2 Coal Steam Virginia 164 2014

Yuma 524 3 Combustion Turbine Colorado 0.2 2015

## 204