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Climate Challenge Participation Accord
DOE's Energy Partnerships for a Strong Economy
1996 Update to
Entergy Service, Inc. and Department of Energy
Climate Challenge Participation Accord
Entergy has updated the original Climate Challenge Participation Accord signed in 1995 as described in the items below.
I. Utility Commitments
A. (1) Industry Initiatives
a) Per Entergy's commitment under I.A.(1)(a), the company has monitored the development of the Electro-technology Investment Fund, but has determined not to participate in this program. Entergy will continue to monitor the economic feasibility of this initiative.
b) In addition to Entergy's commitment under I.A.(1)(b), the company will increase its investment to include a total of $100,000 between 1995 and 1999 to participate in the Utility Forest Carbon Management Program and will serve as a member company on the Board of Directors of the Utilitree Carbon Co. $40,000 has already been invested.
c) Per Entergy's commitment under I.A.(1)(c), the company has monitored the development of the National Earth Comfort Program, but has determined not to participate in this program.
d) Per Entergy's commitment under I.A.(1)(d), the company has monitored the development of the International Utility Efficiency Partnerships Organization, but has determined not to participate in this program.
(2) Company Activities
a) Nuclear Availability Improvements: Entergy's estimate of the amount of reductions in CO2 from these projects has increased to 9,251,000 tons (compared to 1995 estimate of 8,694,000 tons) of CO2 through the year 2000. These changes are due to better than expected performance at the River Bend and Waterford 3 Nuclear Facilities in 1995 and an increase in projected performance in all units through 2000.
b) Nuclear Capacity Upgrade Projects: This effort will result in the reduction of over 2,463,550 tons of CO2 through the year 2000. This is a 107,450 ton net decrease from original estimates due to the cancellation of projects at Arkansas Nuclear One. Some of this loss is made up by the addition of projects at River Bend Station. In addition, for certain projects listed in the original accord, assumptions were adjusted to reflect 1995 actual performance and revised 1996-2000 projections.
c) Fossil Station Efficiency Upgrades: These projects will result in the reduction of over 2,053,873 tons of CO2 through the year 2000 as compared to Entergy's original estimate of 1,908,000 tons. There are many changes under this category of projects including the addition of projects at White Bluff Unit 1, White Bluff Unit 2, Lake Catherine 4, Michoud 3, and Willow Glen 5. In addition, for certain projects listed in the original accord, assumptions were adjusted to reflect 1995 actual performance and revised 1996-2000 projections.
d) Renewable Generation: The Vidalia Hydroelectric Project will result in the reduction of over 5,825,000 tons of CO2 through the year 2000. This is almost a 500,000 ton increase over Entergy's original estimate and reflects actual 1995 data and revised projections through the year 2000.
e) Energy Efficiency Services: This project and its estimated reductions of over 6,653,800 tons of CO2 through the year 2000 have not changed.
f) Electrotechnology Projects: These projects could result in a net reduction of over 148,008 tons of CO2. Note that the Electric Motors for Natural Gas Compression project, which is still being implemented, has been removed as a commitment under the Climate Challenge plan because of the difficulty in tracking its impact on customers who are outside of this company. Entergy may reconsider this program if an adequate, simple, and cost effective tracking program is developed.
g) Transmission & Distribution Efficiency Projects: These projects will result in a net reduction of over 1,152,100 tons of CO2 as compared to Entergy's original estimate of 1,123,900 tons. This represents revised estimates based on 1995 performance and new 96- 2000 projections.
h) Forestry Carbon Management Projects: These projects will result in the sequestration of over 1,811,900 tons of carbon through 2025 as compared to Entergy's original estimate of 82,500 tons through 2000. Since signing its Accord, Entergy has begun a project to sequester carbon through forestry projects at under utilized properties. Entergy has also revised the wetland project assumptions to reflect revised project schedule.
i) Transportation Fleet Projects: Entergy has removed Vehicle Emission Testing and Airplane Travel projects from this Accord. There were no estimates for these projects in the original Accord and it has been determined that the reductions are minor, difficult to track, and not worth discussion in the document. Note that the Vehicle Fleet Conversion project is still viable and included in this section.
j) CFC Recovery: These projects are continuing as planned.
Entergy estimates that implementation of these emission reduction strategies will result in a cumulative CO2 reduction of over 27 million tons through the year 2000. This represents an annual reduction of over 4 million tons in the year 2000. Details of these projects are shown in Attachment 1, which replaces Attachment 1 (February 15, 1995) to Entergy's Accord.
Entergy has designated an alternate Climate Challenge Program representative. This is:
(Alternate) Mr. Jim Schott
P.O. Box 2951
Beaumont, TX 77704-2951
Tab III
Industry Initiatives
Entergy is an active participant inthe Utility Forest Carbon Management Industry Initiative developed by the Edison Electric Institute and the utility industry.
Utility Forest Carbon Management Program
Entergy has made a $100,000 commitment to the Utilitree Carbon Corporation as part of the Utiltiy Forest Carbon Management Program. As trees and other vegetation grow, they consume carbon dioxide (CO2) from the atmosphere. CO2 is one of the main greenhouse gases. Trees are referred to as "carbon sinks", because they take CO2 out of the air and store it in living plant tissue. About one-half of a tree is carbon. Wetland grasses are another excellent carbon sink.
The goals of the utility Forest Carbon Management Program are to:
- Advance the state of knowledge regarding options for managing greenhouse gases via forestry;
- Assist in reporting forestry activities under section 1605(b) EPAct of 1992;
- Implement projects to manage greenhouse gases;
- Promote environmental stewardship by the utility industry to demonstrate that a voluntary approach can work;
- Establish low-cost forestry options to manage greenhouse gases;
The Utility Forest Carbon Management Program evaluated over 30 proposals addressing the reduction of deforestation and harvest impacts to reduce CO2 emissions and maintain carbon sinks, enhance existing carbon sinks, create new carbon sinks, store carbon in wood products, enhance energy conservation, and biomass. Six projects have been approved including four inthe United States and two international.
Entergy has made a commitment of 100,000 through the year 1999. An investment of $40,000 has been made to date. Entergy is a member company in the Utilitree Board of Directors.
Attachment 1
Projects and Initiatives
Entergy has undertaken or will undertake greenhouse gas emission reduction projects under the ten categories listed in the Table below. A summary of total emissions reduced from all projects from 1990 through the year 2000 is shown in this table. Summary descriptions of each project and the assumptions leading to these calculations are described in the following sections. The total direct emission reduction for the Entergy Generation System is 18,840,015 tons which reflects all projects below except for Energy Efficiency Systems, Forestry Carbon Projects, Transportation Projects, and CFC Phaseout and Recovery.
Greenhouse Gas Reduction Project Category Reductions (Tons of
CO2)
1. Nuclear Unit Availability Improvements 9,251,000
2. Nuclear Unit Capacity Upgrades 2,463,550
3. Fossil Plant Efficiency Upgrades 2,053,873
4. Renewable Generation 5,825,000
5. Energy Efficiency Services 6,653,857
6. Electrotechnology Projects 148,008
7. Transmission and Distribution Efficiency Projects 1,152,134
8. Forestry Carbon Management Projects 61,500
9. Transportation Fleet Projects 750
10. CFC Recovery and Recycling Undetermined
Total Greenhouse Gas Reductions 27,609,672
1. Nuclear Availability Improvements
Raise Nuclear Unit Targets on Annual Capacity Factor
Brief Description
This initiative establishes new and increased targets for average annual capacity factors of the Entergy Arkansas Nuclear One, Grand Gulf, Waterford, and Riverbend nuclear units from the 1990 projected levels of 81% to a new level of 87%. A successful effort will result in an increase in energy production from the nuclear units. This initiative will offset fossil generation and help Entergy reduce its green house gas emissions. The Riverbend and Grand Gulf Nuclear Stations are co-owned. Entergy owns 70% of Riverbend and 90% of Grand Gulf. Only this ownership share is used to estimate reductions from the Entergy fossil system at 0.7 tons per MWh. The following is an estimate of the amount of CO2 emissions avoided by this program.
GHG Emissions Impacts
POTENTIAL GHG REDUCTION FROM CF IMPROVEMENT PROGRAMS
Year Entergy Ownership ANO1 ANO2 GG1 WF3 RB Total
of
1995 CO2 Emissions 229 -60 183 398 813 1,564
1996 Avoided 336 277 358 347 0 1,319
1997 in 1,000 Tons 256 331 286 396 201 1,470
1998 322 334 358 396 683 2,093
1999 322 211 358 330 0 1,221
2000 256 334 358 396 241 1,585
1990-2000 Entergy Ownership 1,721 1,427 1,902 2,262 1,938 9,251
Note that 1995 data above indicates actual performance and generation for the year. A work table indicating the anticipated capacity factor improvements follows.
![[Table]](table1.gif)
2. Nuclear Unit Capacity Upgrades
Nuclear Unit Thermal Rating Upgrade Project
Brief Description
This project will raise the licensed thermal rating of three Entergy nuclear units by gaining approval to operate them at a higher power level than they are currently licensed to operate. The program is being carried out at the Riverbend, Grand Gulf, and Waterford Nuclear Stations. The benefits from the program will result in an increase in energy production from the nuclear units. This project has been modified since the initial Climate Challenge Accord. The Arkansas Nuclear One project has been eliminated and replaced with an uprate of the Riverbend Nuclear Station.
The Riverbend and Grand Gulf Nuclear Stations are co-owned. Entergy owns 70% of Riverbend and 90% of Grand Gulf. CO2 emission reductions are only claimed for the % ownership of these stations which will offset Entergy fossil production at 0.7 tons per MWh.
The project would offset fossil generation and help Entergy reduce its green house gas emissions. The following is an estimate of the amount of CO2 emissions avoided by this program.
GHG Emissions Impacts
GHG REDUCTION FROM NUCLEAR UNITS THERMAL RATING UPGRADE PROGRAMS
RBS GGNS WSES3 Total
1999 MW Raised 42 NA NA 42
2000 42 62 72 176
1999 Capacity Factor 83% NA NA
2000 83% 95% 83%
1999 GWH Increase 305 0 0 305
2000 305 516 523 1,345
1999 1000s Tons CO2 214 0 0 214
2000 Avoided 214 361 366 941
Total Entergy Share 418 361 366 1,128
Grand Gulf Nuclear Station Turbine Upgrade
Brief Description
The proposed turbine upgrade at Grand Gulf, a single unit nuclear plant located in Claiborne County, Mississippi, consists of new blading and ancillary equipment for the turbines. The benefits from the turbine upgrade work include increased energy and capacity as a result of the increased efficiency of the turbines and the avoidance of more maintenance on the existing turbines. The upgrade will not require any increase in fuel consumption or fuel cost.
As a result of the efficiency improvements, the new designed stationary blading, new rotor with additional rows of blades, and new cylinders in the LP and HP turbines, is estimated to yield about 65 MW of additional capacity at Grand Gulf (45 MW from LP and 20 MW from HP upgrades). Entergy therefore could reduce its dependency on other fossil generating stations. Since Entergy owns 90% of the unit, 58.5MW of the increased capacity will accrue to Entergy. Grand Gulf's increased capacity will offset fossil generation and help Entergy reduce its green house gas emissions. The following is an estimate of the amount of CO2 emissions avoided by this project.
GHG Emissions Impacts
POTENTIAL GHG REDUCTION FROM GGNS TURBINE UPGRADE PROGRAMS
Year Available Increase CO2 Avoided
MW MWH Tons
1995 20.7 157,759 110,431
1996 33.3 239,201 167,440
1997 33.3 274,206 191,440
1998 45.9 329,709 230,796
1999 58.5 420,217 294,152
2000 58.5 486,837 340,786
Total 1,335,550
3. Fossil Plant Efficiency Upgrades
Independence Unit 1 (ISES 1)
Efficiency Improvement Projects
Brief Description
The Independence Plant is located near Newark, Arkansas. The station consists of two coal units with a total combined capacity of 1678 MW that went into commercial operation in the 1980s. ISES Unit 1 is co-owned by several utilities of which Entergy is the majority owner with 88.8%. The high pressure feedwater heater on Unit 1 was replaced in 1995. The heater had frequent tube leaks that required 50% of the feedwater to bypass the heater and a large number of tubes had been plugged which reduced efficiency of the unit. Replacement of the heater resulted in approximately a 2 percent improvement of unit heat rate. The project is estimated to have saved 207 Btu/kw beginning in 1995.
The total emission reductions through the year 2000 is 724,485 tons for the entire unit. The Entergy share of this total is 643,342 tons. Total carbon dioxide emission reductions from this project is described below.
Louisiana Station 1 Repowering & Unit Upgrade
Brief Description
The Louisiana Station 1 is located near Baton Rouge, Louisiana, adjacent to the Mississippi River. All steam and electric power from Louisiana Station 1 is dedicated to the nearby Exxon Baton Rouge Refinery for industrial use. The station currently has four boilers, one combustion gas turbine/heat recovery steam generator (GT/HRSG), and three steam turbines. The station burns natural gas and refinery gas from the Exxon refinery/chemical plant complex.
Entergy is proposing to initiate a major expansion at the station beginning in 1996 with completion in late 1997. The main elements of the expansion consist of the following:
- Installation of one 150 MW gas combustion turbine with associated heat recovery steam generator
- Refurbish three boilers
- Upgrade existing gas turbine
The addition of the new equipment, the reduction in operation of existing boilers, and other modifications will help Entergy reduce its greenhouse gas emissions. It is estimated that this repowering and upgrade project will reduce annual CO2 emissions by approximately 33,533 tons.
Annual GHG Emissions Reductions
1998 1998 2000 TOTAL ANNUAL TONS OF CO2 33,533 33,533 33,533 100,599 AVOIDED:
GHG EMISSIONS REDUCTION ANALYSIS:
________________________________________________________________________________
Increase Decrease
New CT/HRSG 1473 MMBtu/hr -
Reduce operation of 3 boilers from 836 MMbtu/hr to
533 Mmbtu/hr
(2508 MMBtu/hr - 1599 MMBtu/hr =
909 MMBtu/hr) - 909 MMBtu/hr
Maintain No. 9 boiler on cold standby. - 630 MMBtu/hr
TOTAL 66 MMBtu/hr
Modifications would reduce station heat input by 66 MMBtu/hr.
(66 MMbtu/hr x 116 #CO2/MMBtu x 8760 hrs. x 1 ton/2000# = 33,533 CO2 tons annually.
Sabine Unit 2
Efficiency Improvements
Brief Description
The Sabine Plant is located at Bridge City, Texas, in the southeast corner of the state. The station consists of five gas and oil units with a total combined capacity of 1890 MW. The high pressure feedwater heater on Unit 2 was replaced in 1995. The heater had a large number of tubes plugged which had reduced plant efficiency. A new designed heater was installed to correct tube failure problems. Replacement of the heater resulted in an approximate 2 percent improvement of unit heat rate. Total emission reduction estimates are provided below.
White Bluff Unit 1
Efficiency Improvement Projects
Brief Description
The White Bluff Plant is located at Redfield, Arkansas, between Pine Bluff and Little Rock. The plant consists of two coal units with a total combined capacity of 1659 MW. Unit 1 is a co-owned unit in which Entergy is the majority owner with 57.1%. The high pressure feedwater heater on Unit 1 was replaced in 1995. Replacement of the heater corrects a design weakness in the original heater that has cause frequent tube leaks. An excessive number of leaking tubes plugged has resulted in reduced unit efficiency. Economizer Ash Removal System upgrades will reduce the power consumption of this unit by allowing pumps to be run only when pulling bottom as rather than continuously. The installation of additional sootblowers will reduce the reheat spray about 40%. The Economizer Ash Removal System and Sootblower projects will be completed in 1996. In total, these projects are anticipated to improve heat rate by over 2 percent beginning in 1996.
The total emission reductions through the year 2000 is 655,540 tons for the entire unit. The Entergy share of this total is 374,313. Total carbon dioxide emission reductions from these two projects are described below.
Ninemile Units 4 and 5
Efficiency Improvement Projects
Brief Description
The Ninemile Plant is located at Westwego, Louisiana, on the Mississippi River near New Orleans. The plant consists of 5 gas and oil units will a total combine capacity of 1827 MW. The Ninemile Unit 4 and 5 low pressure turbines (LP) were replaced with new designed turbines, which included LP rotors, stationary blades, inner cylinders and steam seals. The LP turbine retrofits improved heat rates by about 1.6 percent for Unit 4 and 1.1 percent for Unit 5. Emission reduction totals are summarized below.
White Bluff Unit 2
Efficiency Improvement Projects
Brief Description
The White Bluff Plant is located near Redfield, Arkansas. The station consists of two coal units with total combined capacity of over 1600 MW net that went into commercial operation in the 1980s. Unit 2 is a co-owned unit of which Entergy is the majority owner with a share of 59.1%. During 1996, Unit 2 at this facility installed four additional soot blowers in the finishing superheat section. A net efficiency improvement of 16 Btu/kw is expected due to the reduction of reheat spray flows from 100 KLb to 40 KLb per hour and improved heat transfer. In addition, this unit will install a new economizer ash removal system that will allow bottom ash to be pulled using only one pump and result in an efficiency savings of 0.93 MW. An expected net efficiency improvement of 10 Btu/kw is expected for this project. Savings from these projects will be realized starting in 1997 and will result in a total of 26 Btu/kw.
The total emission reductions through the year 2000 is 63,292 tons for the entire unit. The Entergy share of this total is 37,405 tons. Total carbon dioxide emission reductions from these two projects are described below. Emission reductions and assumptions are summarized below.
Lake Catherine Unit 4
Efficiency Improvement Projects
Brief Description
Lake Catherine Plant is located near Hot Springs, Arkansas. Unit 4 burns natural gas. In 1996, flexible air preheater seals were installed to reduce air leakage from the air side to the gas side. This will result in a reduction of fan power required to move air into the furnace. An expected net efficiency improvement of 10 Btu/kw will be realized in 1997. It will also allow an additional 10 MW of summer natural gas capacity. Emission reductions and assumptions are summarized below.
Michoud Unit 3
Efficiency Improvement Projects
Brief Description
The Michoud Plant is located outside of New Orleans, Louisiana. Unit 3 was designed with air preheater baskets to accomodate oil. In 1996, these baskets will be converted to gas only which will allow more efficient heat transfer to combustion air. This is expected to result in a heat rate improvement of 213 Btu/kw beginning in 1997. The Forced Draft fan power consumption will be reduced by improving aerodynamics through modification of the existing inlet cones. This will result in a 17 Btu/kw improvement beginning in 1997. A feedwater project will eliminate drain excursiosn to minimize leadage to the condenser resulting in an improvement of 12 Btu/kw. All together, these projects will total 242 Btu/kw beginning in 1997. Emission reductions and assumptions for these projects are provided below.
Lewis Creek Units 1 and 2
Efficiency Improvement Projects
Brief Description
Lewis Creek Power Plant is located in Montgomery County near Conroe, Tx. The plant consists of two units with a total capacity of approximately 500 MW. Each unit is a natural gas fired, Combustion Engineering opposed fired boilers with a maximum rated capacity of 2642 MMBtu/Hr each. During 1994, Units 1 and 2 upgraded control systems and installed CO monitors in the ductwork. n combination, these projects have enabled operators to better control the combustion process on both units. CO2 reductions are a result of heat rate improvements resulting from better process optimization and low excess air firing possible with the new control system. The project assumes a 0.5% heat rate improvement beginning in 1995.
Nelson Unit 4
Efficiency Improvement Projects
Generic NOx Control Intelligen System (GNOCIS) is an "intelligent" neural network software system which is integrated into a distributed control system, receives on-line data from multiple operating parameters, and advises operators on what boiler conditions should be modified to improve NOx, heat rate, or other operating parameters. The objective of this project is to demonstrate this on-line enhancement to an existing Digital Control System at Nelson Unit 4 and quantify NOx and heat rate improvements while meeting other operational constraints. A further objective is to completely integrate the system so that boiler improvements are made automatically by GNOCIS with no operator interface. This would allow continuous and constant minimization of emissions and boiler efficiency. If successful, this technology could ultimately be applied to other advanced control systems at Entergy and througout the United States and perhaps the world. Emission reductions in NOx, CO2, CO, and organics are expected. A heat rate improvement of 0.2% is assumed beginning in 1997.
GNOCIS will aid operators in dispatching boilers to minimize NOx by advising optimal settings for boilers that are not always obvious. GNOCIS models efficiency, the production of NOx, or any other parameter of concern by learning the relationship of multiple plant operating parameters. It then gives advide to operators that optimizes those parameters to minimize NOx formation while meeting other operating constraints.
Willow Glen Unit 5
Efficiency Improvement Projects
Brief Description
Willow Glen Unit 5 is a 560 MW gas fired unit located in Baton Rouge, Louisiana. THis project will replace the boiler feed pump seal water drain traps with volume tanks and level control valves. This will prevent entrained air in the seal water from entering the condenser. It is expected to result ina 10 Btu/kw improvement beginning in 1998. Emission reductions and assumptions for this project are summarized below.
4. Renewable Generation
Commercial Operation of Vidalia Hydroelectric Station
Brief Description
Vidalia, constructed by the City of Vidalia, is a Run-of-the-river Hydroelectric Generating Project of eight 24 MW generating units that supply 192 MW of capability. Current projections of water volumes available for electric generation will limit capacity to a maximum of 151 MW. In 1990, LP&L began purchasing 91-94% of the total power from this hydroelectric project which has displaced fossil generation.
5. Energy Efficiency Services
Integrated Solutions, Inc. Energy Efficiency Services
Brief Description
Entergy's Integrated Solutions, Inc. subsidiary is an energy management company providing hassle-free energy efficiency services to commercial and industrial customers. These services include lighting, HVAC, refrigeration, and energy management systems. Using state-of-the-art technologies and full-service maintenance, ESASI is able to guarantee energy savings and service over the life of the contract. These services are fully financed by ESASI and are funded out of the savings achieved.
By utilizing integrated service packages, ESASI is able to reduce the demand for energy, lower customer energy bills and maintenance costs, reduce the need for new power plants, and minimize environmental emissions like NOx, SOx, and CO2. These benefit the customer, regional air quality, and the local economy. Expected CO2 emission reductions are 6,653,800 tons of CO2 through the year 2000.
GHG Emissions Impacts
POTENTIAL GHG EMISSIONS REDUCTION FROM ENERGY EFFICIENCY SERVICES
1993 1994 1995 1996 1997 1998 1999
ENERGY (MWH)
LIGHTING 15,148 104,384 413,724 756,592 750,165 750,165 750,165
HVAC 0 0 56,584 419,780 1,104,954 1,211,228 1,211,228
TOTAL 15,146 104,384 470,306 1,176,372 1,855,119 1,961,393 1,961,393
TONS OF CO2
LIGHTING 10,602 73,069 289,605 529,614 525,116 525,116 525,116
HVAC 0 0 39,609 293,846 773,468 847,860 847,860
TOTAL 10,602 73,069 329,214 823,460 1,298,583 1,372,975 1,372,975
Note: Years 2000-2004 same as Year 1999. Also assume 0.7 Tons of CO2 per MWH.
6. Electrotechnology Projects
Texas Eastern Natural Gas Compressor Station
Brief Description
The Texas Eastern Natural Gas Compressor Station is located near Cleveland, Texas in Entergy's service territory. The station was upgraded in 1994 by replacing eight internal combustions engines with three electric drives rated at 16 megawatts total. The electric compressors will be base loaded and peaking will be achieved using the older internal combustion compressors. The internal combustion engines replaced, produced an annual equivalent of 103,150 tons of green house gas CO2 emissions. The following is an estimated annual projection of the amount of green house emissions avoided by replacing internal combustion engines with electric motors.
GHG Emissions Impacts
Texas Eastern Natural Gas Compressor Station
PROJECTED GHG EMISSIONS AVOIDED
95 96 97 98 99 2000 Total ANNUAL GENERATION 112,128 112,128 112,128 112,128 112,128 112,128 672,768 (MWH) ANNUAL TONS OF 24,668 24,668 24,668 24,668 24,668 24,668 148,008 CO2 AVOIDED
(Work Paper)
Texas Eastern Natural Gas Compressor Station
Assumptions and Calculations
1. Three electric motors rated at 16 MW
2. 80% Annual Load Factor
3. Annual 112,128 MWH's
4. Entergy Generation is 0.7 Tons per MMBtu
5. Internal Combustion Engine gas is 115 Lb/MMBtu or .92 Tons per MMBtu
Heat Rate of:
Internal combustion Engine => 16,000 Btu/Kwh
Steam Turbine Cycle => 10,500 Btu/Kwh
Fuel requirements for 112,128 MWH's
| MWh | Tons CO2 | |
| Internal Combustion | 112,128 | 103,158 |
| Entergy Generation | 112,128 | 78,490 |
| Annual Tons of CO2 Avoided | 24,668 |
7. Transmission and Distribution Efficiency Projects
Transmission and Distribution Efficiency Projects
Brief Description
Entergy will undertake several projects to reduce the efficiencey losses from the transmission and distribution of electricity. By conducting these projects, Entergy will reduce greenhouse gas emissions by reducing energy losses measured in megawatt-hours. Each MWh saved represents a reduction in greenhouse gases as it will not be necessary to generate this electricity in the system. The majority of projects include upgrades of transmission lines (three per year) and capacitor bank additions (five per year). In addition, Entergy will undertake other specific projects at substations and other facilities to reduce these emissions. All together, these T&D efficiency projects will result in a decrease of 1,152,134 Tons of CO2 through the year 2000. Details of each project appear in the following pages.
GHG IMPACT OF ESTIMATED ANNUAL LOSSES SAVINGS
FROM TRANSMISSION PROJECTS (1990 - 2000):
METHODOLOGY AND ASSUMPTIONS
METHODOLOGY:
1. 1995 Summer Peak model was used to simulate losses.
2. For projects resulting in branch additions or impedance changes:
Annual Losses Reduction = (Peak Losses Change)(Annual Load Factor)(8760 hr/yr)
3.For capacitor bank additions:
Annual Losses Reduction = (Peak Losses Change)(Annual Load Factor)(8760 hr/yr)(usage factor)
4. Major transmission and/or substation modifications causing impact were studied, including auto addition, line voltage conversion, line reconductoring / upgrade, line addition, removal, and/or reconfiguration, and capacitor bank addition.
ASSUMPTIONS:
1. Entergy's Annual Load Factor = 60%.
2. Average annual number of transmission line rebuilds (same voltage) =
3
2. Average usage factor for capacitor banks = 40%
3. Average size of capacitor bank addition = 33 MVAR
4. Average annual number of capacitor bank additions = 5
5. 1 MWh of losses = 0.7 tons of CO2
![[Table]](table2.gif)
8. Forestry Carbon Management Projects
Wetlands and Carbon Sequestration
Brief Description
Wetlands are an excellent "carbon sink", especially in coastal wetlands that are eroding, because the sequestration of carbon in these wetlands is permanent, rather than temporary. This is due to the fact the as the carbon is sequestered by the wetland grasses, subsidence covers theses plants and provides substrate for new grasses to grow. This permanent sequestration adds to the unique nature of such wetlands. Virtually all of the coastal wetlands in Entergy's service territory exhibit this characteristic.
All of the Gulf Coastal Wetlands from Beaumont, Texas to Louisiana's eastern border are part of Entergy's service territory. Protecting America's wetlands is a national concern that Entergy must address while still assuring our mandate to provide service at a fair and reasonable rate. Assuring that mandate is becoming more difficult in wetland areas. Since the release of the National Wetlands Policy Forum's "no net loss" of wetlands report in 1988, considerable attention has been focused on how to improve the wetlands protection afforded by the Clean Water Act, Section 404 dredge and fill permit program, which governs operations in wetlands. Section 404 requires that adverse ecological impacts of a wetland development project be mitigated.
Entergy has begun to address that requirement by exploring the development and enhancement of coastal wetlands as mitigation for future activities. This enhancement increases the ability of these wetlands to sequester carbon by approximately three (3) tons per acre per year. Entergy plans to begin two projects in 1995 that should begin to sequester carbon at this increased rate by 1996.
Southeast Texas Project:
Within the Neches River watershed in Orange County, Texas, Entergy has approximately 1500 acres of brackish marsh in various stages of deterioration. The company has proposed that the Southeast Texas Regional Planning Commission grant a conservation easement in order to pursue creation of a regional wetlands mitigation bank. If the project proceeds, it will result in increased carbon sequestration in 1996. The project will modify the hydrology to allow sediment to build and subsequently be colonized by wetland plants. These wetland plant in turn sequester carbon. The project will result in increased carbon sequestration of 4,500 tons per year beginning in 1998. Total carbon sequestered is shown in the table below.
Southeast Louisiana Project:
This project is located in Jefferson Parish, Louisiana. Entergy plans to enhance 4000 acres of degraded wetlands by modifying the existing hydrologic regime and planting wetland grasses. These wetland plants in turn sequester carbon in an area that was formerly open water. The project will result in increased carbon sequetration of 12,000 tons per year beginning in 1998. To date, approximately 2,000 acres have been restored beginning in 1996. Total carbon sequestered is shown in the table below.
Project Acres Sequest Tons Tons Tons Tons Tons 2000 Total
Rate 1996 1997 1998 1999 Tons
Southeast 1500 3 Tns/ 0 0 4,500 4,500 4,500 13,500
Texas Acre/Yr
Southeast 4000 3 Tns/ 6,000 6,000 12,000 12,000 12,000 48,000
Louisiana Acre/Yr
Entergy Forestry Projects at Underutilized Properties
Carbon Sequestration
Brief Description
Entergy has begun a project to manage properties throughout its system for the sustained yield of timber. These properties range from open fields to mature forests. Many sites are mixed field/forest. This project will involve the management of sites by planting trees to create new forests for timber production at open sites. In addition, mature forests will be selectively cut and replanted to increase forest growth and thus carbon sequestration. In this manner, carbon sequestration rates will be increased dramatically by the progressive management of sites which had reached maturation.
Currently, there are fifteen sites in the Entergy system for which management plans have been or are being developed. These projects represent a total of 23,945 acres. The projects are listed below.
Site Acreage Current Use Planned Use
Moses Plant 260 Mixed Timber/Agriculture
Spring Mountain Pump, AR 1,129 Forest Timber
White Bluff Plant 3,536 Forest TImber
Mayflower, AR 150 Forest TImber
Eldorado, AR 150 Forest Timber
Nelson Plant 1,686 Open Field Timber
River Bend Plant 3,445 Forest Timber
Waterford Plant 3,594 Mixed Timber/Agriculture
I-12 and O'Neal, LA 79 Forest Timber
Baxter Wilson Plant 1,464 Mixed Timber
Fort Adams, MS 2,270 Forest Timber
Grand Gulf Plant 2,169 Mixed Timber
James Crossing, MS 867 Mixed Timber/Agriculture
Rex Brown Plant 104 Mixed Timber
Blue Hills, TX 3,032 Forest Timber
Acreage 30 Year 30 Year Tons
Tons Carbon Carbon Dioxide
Total Acreage 23,945 359,175 1,316,975
Assume that the 23,945 acres is a mixture of open field and mature forests that will be replanted with mixture of botomland and natural pine growth over a 30 year planning horizon. Use an average for natural pine and hardwood forest at net benefit of 30,000 Lbs/acre carbon at 30 years. The total sequestration for these projects over 30 years will be 359,175 tons of carbon or 1,316,975 tons of CO2 equivalent.
9. Transportation Fleet Projects
Vehicle Fleet Conversions
Brief Description
Entergy operates a large service fleet throughout its four state service area to maintain power limes and provide customer service. These vehicles range from standard gasoline powered automobiles and trucks to large diesel fueled man-lift trucks. Over the next several years, Entergy will convert some of its light-duty fleet to clean burning natural gas. This conversion should be complete by the year 2000. This will result in reductions of CO2, CO, NOx, and volatile organic compounds. Estimated reductions of CO2 in the year 2000 are 750 tons.
10. CFC Recovery and Recycling
CFC Recovery and Recycling
Brief Description
Entergy expects to significantly reduce the amount of CFC and HCFC releases at all office, power plants, and garages in its system through recovery and recycle of refrigerants in air conditioning and cooling systems. In 1993, all facilities began the use of refrigerant recovery units when servicing air conditioning and cooling systems. In most cases, work is carried out by contracted service companies which have technicians trained in the use of the equipment. In other instances, Entergy personnel have received training and the recovery of CFCs and HCFCs is being conducted with company equipment. All recovered freon is re-used or sent to a recycler. In the past, refrigerants have typically been vented to the atmosphere when repair work was carried out on air conditioning and cooling systems. This project has significantly reduced the emissions of various CFC and HCFC's. Entergy has not as yet estimated CFC emission reductions.
CFC Phaseout
Entergy plans to gradually phase out CFC products over the long term. However, Entergy has not as yet estimated emission reductions associated with this phase out.
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Lawrence.Mansueti@hq.doe.gov