20060728IPC to Staff 59.pdf

IDAHO POWER COMPANY R E eEl V EDO. BOX 70
BOISE, IDAHO 83707
An IDACORP Company 2006 JUL 27 PH~:
IDAHO PUBLIC
UTILITIES COMMISSION
Monica Moen
Attorney
July 27 2006
Jean D. Jewell, Secretary
Idaho Public Utilities Commission
472 West Washington Street
P. O. Box 83720
Boise, Idaho 83720-0074
Re:Case No. IPC-06-
Idaho Power Company s Response to the First Production Request of
Commission Staff
Dear Ms. Jewell:
Please find enclosed for filing an original and two (2) copies of Idaho Power
Company s Response to the First Production Request of Commission Staff regarding the
above-described case.
I would appreciate it if you would return a stamped copy of this transmittal letter
to me in the enclosed self-addressed stamped envelope.
Very truly yoursfb~
Monica B. Moen
MBM:sh
Enclosures
Telephone [phone] Fax [phone] E-mail MMoen(?i);dahopower.com
BARTON L. KLINE ISB #1526
MONICA B. MOEN ISB #5734
Idaho Power Company
P. O. Box 70
Boise, Idaho 83707
Telephone: [phone]
FAX Telephone: [phone]
RECEIVED
2006 JUL 27 PH~: 37
IDAHO PUBLIC
UTILITIES COMMISSION
Attorney for Idaho Power Company
Street Address for Express Mail
1221 West Idaho Street
Boise , Idaho 83702
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION
OF IDAHO POWER COMPANY FOR A
CERTIFICATE OF PUBLIC CONVENIENCE
AND NECESSITY FOR THE RATE BASING
OF THE EV ANDER ANDREWS POWERPLANT.
CASE NO. IPC-06-
IDAHO POWER COMPANY'
RESPONSE TO THE FIRST
PRODUCTION REQUEST OF
COMMISSION STAFF
COMES NOW, Idaho Power Company ("Idaho Power" or "the Company
and in response to the First Production Request of the Commission Staff to Idaho Power
Company dated June 16, 2006, herewith submits the following information:
IDAHO POWER COMPANY'S RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page
REQUEST NO. 59: Please provide a copy of any analysis showing the
costs associated with converting and operating the Danskin project as a combined cycle
plant.
RESPONSE TO REQUEST NO. 59: Please refer to the document attached
hereto as "Response to Request No. 59.
The response to this request was prepared by Karl Bokenkamp, General
Manager, Power Supply Operations and Planning, Idaho Power Company, in
consultation with Barton L. Kline, Senior Attorney, Idaho Power Company.
~~ (8.
MONICA B. MOEN
Attorney for Idaho Power Company
IDAHO POWER COMPANY'S RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 2
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that on this 2ih day of July, 2006, I served a true and
correct copy of the within and foregoing IDAHO POWER COMPANY'S RESPONSE TO
THE FIRST PRODUCTION REQUEST OF COMMISSION STAFF upon the following
named parties by the method indicated below, and addressed to the following:
Commission Staff Hand Delivered
Donovan Walker US. Mail
Deputy Attorney General Overnight Mail
Idaho Public Utilities Commission FAX
472 W. Washington (83702)Email: Donovan.walker(g)puc.idaho.gov
O. Box 83720
Boise, Idaho 83720-0074
Industrial Customers of Idaho Power Hand Delivered
Peter J. Richardson, Esq.US. Mail
Mark Thompson Overnight Mail
Richardson & O'Leary FAX
515 N. 27th Street Email: peter(g)richardsonandoleary.com
O. Box 7218 mark (g)richardsonandolery .com
Boise, Idaho 83702
Don Reading Hand Delivered
Ben Johnson Associates US. Mail
6070 Hill Road Overnight Mail
Boise, Idaho 83702 FAX
Email: dreading(g)mindspring.com
tl3
Monica B. Moen
CERTIFICATE OF SERVICE , Page
ID AH POWER CO MP ANY
CASE NO. IPC-O6-
FIRST PRODUCTION REQUEST
OF COMMISSION STAFF
RESPONSE TO
REQUEST NO. 59
Sega Inc.
Engineering and
Technical Services
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MISSION STATEMENT
Sega s mission is to provide the nation
with the highest level of professional services
consistent with our QE2 principles.
Quality, Ethics, and Economics
PRINCIPLES
We Strive To...
Treat others precisely how we want to be
treated; that is, honestly, respectfully, and friendly.
This is the foundation of our standard of
ETHICS and is our number one priority.
Provide unmatched professional services that
consistently meet or exceed our clients' business
needs and expectations. This is our signature of
QUALITY.
Deliver services to our clients that yield the
highest benefit-to-cost ratio for their investment
in Sega while generating a reasonable profit for
our firm. This will assure that our client relation-
ships are built on a solid foundation of business
ECONOMICS.
Sega Inc.
16041 Foster
O. Box 1000
Stilwell, KS 66085
Phone: [phone]
Fax: [phone]
www.segainc.com
info (g) segainc.com
07/06 Rev, 3
BRas
ENGINEERING & TECHNICAL SERVICES
An IDACORP Company
EV ANDER ANDREWS COMPLEX
COMBINED-CYCLE
CONVERSION STU
DECEMBER 2002
PRELIMINARY DRAFT
Sega Project No. 02-9999-05
' ', "
18\
,"-i~ iff)~~
::'
December 10 200~
TABLE OF CONTENTS
SECTION 1
SECTION 2
SECTION 3
SECTION 4
SECTION 5
APPENDICES
Page No.
EXECUTIVE SUMMARY
INTRODUCTION 2 -
Purpose
Scope of Services
2 - 1
2 - 1
DETERMINATION OF PLANT CONFIGURATION 3 -
Description of Existing Site
Operation Design Basis
Review of New HRSG Design
Review of Cooling Systems
Proposed Plant Design
3 - 1
3 - 2
3 - 2
3 - 6
3 - 8
COMBINED-CYCLE PLANT PERFORMANCE 4 -
CAPITAL COSTS 5 -
Plant Layout 5 - 2
Capital Costs
Thermoflow Model Outputs
Vendor Pricing Summary Sheet
Vendor Quotes
Idaho Power Company
Preliminary Draft
Sega Project No. 02-9999-
December 10, 2002
EXE C UTIVE SUMMARY
Idaho Power Company authorized Sega Inc. to perform an engineering study to develop a
conceptual design and opinion of probable cost for conversion of the peaking gas turbines
the Evander Andrews Complex into a combined-cycle generating plant.Idaho Power
Company is evaluating this potential project as one of several generation expansion alter-
natives in its integrated resource plan (IRP) which will be filed with the Idaho Public
Utilities Commission. The results ofthis study are summarized in Table 1-
Table 1-
Summary of Cost and Performance Data for Different Design Cases
Simple Cycle Combined Cycle - Dry Cooling
Unfired DF to 1500
Incremental Combined-cycle Cost ($)Base $58 003 987
Incremental Duct Fire Cost ($)N /A Base
Net Electrical Output (kW)205 110 639 148 356
Incremental Capacity (kW)Base 31,434 151
Net Efficiency (%, LHV)31.4%43.40,
Net Heat Rate (Btu/kWh, LHV)868 834 343
Incremental Heat Rate (Btu/kWh , LHV)Base 189 5,451
Incremental Capital Cost ($/kW)Base $840 / kW
For this application, it was determined that a dual-pressure HRSG with supplemental
firing is appropriate. Duct burners will supplementary fire to approximately 1500o , which
is normally considered the upper limit of firing without using special technology. The
HRSG would produce superheated steam at 800 psig and 950oF. An air-cooled condenser
will be utilized to minimize water consumption.
The design concept for this plant is to obtain "best bang for the buck" for seasonal peaking.
During normal plant operation, the duct burners would not be fired. The plant is designed
to run most efficiently unfired. However, the steam turbine is oversized and the HRSG
Idaho Power Company
Preliminary Draft Sega Project No. 02-9999-
December 10, 2002
designed to support duct firing for additional peaking capacity. The air-cooled condenser is
sized accordingly.
At the design point defined in Table 1-, net electrical output is approximately 111 MW for
unfired operations. This is a net increase of approximately 32 MW beyond simple-cycle
electrical output. By duct firing to 1500oF at these conditions, net electrical output rises to
148 MW for a net increase of approximately 69 MW. Duct firing more than doubles the
additional generating capacity over that of the simple-cycle plant. Table 1-1 summarizes
the performance outputs for the design point with and without supplementary firing.
Table 1-
Summary of Design Information
Site
Site Location Mountain Home, Idaho
Site Elevation 3212 feet
Ambient Conditions 80oF dry bulb, 60o F wet bulb
:qulpmen
Cooling System Dry Air-cooled Condenser
HRSG Design Information Dual-pressure, Duct Burner, 800 psig 950oF Steam
Steam Turbine Design Information Sliding Pressure , Dual Admission
Steam turbine design is based on the backpressure of the cooling system and the inlet
steam conditions and flows. The steam turbine was sized for the maximum steam flow
from the HRSG. Because the design point is at 80OF and the design includes duct firing,
the maximum design steam flow is based on maximum duct firing at this temperature. At
lower amounts of duct firing or higher ambient temperatures, steam flow to the turbine will
be reduced, In order to allow for this variation in inlet steam conditions, a sliding-pressure
steam turbine would be utilized. Another consideration is the number of steam admissions
into the steam turbine. Because the HRSG is dual pressure and neither pressure is
dedicated to de aeration, the steam turbine would be dual-admission.
Idaho Power Company
Preliminary Draft
1- 2 Sega Project No. 02-9999-
December 10, 2002
Costs were determined for the proposed plant design using Thermoflow(8) outputs and by
contacting vendors.Vendor budgetary pricing generally confirmed budgetary pricing
estimated by Thermoflow(8) for major pieces of equipment. These include the steam turbine
HRSGs, and the air-cooled condenser.
Idaho Power Company
Preliminary Draft
1- 3 Sega Project No. 02-9999-
December 10, 2002
INTRODUCTION
PURPOSE
Idaho Power Company has authorized Sega Inc. to perform an engineering study to develop
a conceptual design and opinion of probable cost for conversion of the peaking gas turbines
at the Evander Andrews Complex into a combined-cycle generating plant. Idaho Power
Company is evaluating this potential project as one of several generation expansion alter-
natives in its integrated resource plan (IRP) which will be filed with the Idaho Public
Utilities Commission. This preliminary draft report summarizes the findings of Sega
study.
SCOPE OF SERVICES
Sega s scope of services for this study included the following:
1. Sega confirmed the operating characteristics of the installed simple-cycle
gas turbines at site conditions.
2. Sega utilized Thermoflow(8) software to develop models of "2-on-l" combined-
cycle plant configurations for this application.
3. Sega created models with three types of cooling systems: air-cooled
condenser, evaporative mechanical draft cooling tower, and wet/dry
combined cooling. These models were evaluated on the basis of water
consumption, overall performance, and costs,
4. Sega created models with and without supplementary firing. Performance
and cost effects were evaluated.
5. Sega recommended a plant configuration that best fits the preferred operat-
ing conditions.
6. Sega contacted vendors to confirm budgetary prICIng, schedule, and
performance characteristics of major equipment.
7. Sega prepared a preliminary report summarizing the findings ofthe study.
Idaho Power Company
Preliminary Draft
2 -Sega Project No. 02-9999-
December 10, 2002
8. Upon receipt of comments from Idaho Power Company, Sega will revise the
report as appropriate and submit a final report to Idaho Power Company.
Idaho Power Company
Preliminary Draft
2 - 2 Sega Project No. 02-9999-
December 10, 2002
DETERMINATION OF PLANT
CONFIGURATION
Idaho Power Company previously installed two Siemens-Westinghouse 251 B12 combustion
turbine generators in a simple-cycle configuration. These turbines were installed in an
arrangement that would allow for conversion to a combined-cycle plant. The purpose of this
section is to define the existing site conditions and evaluate the feasibility and performance
of potential combined-cycle plant design conditions.
The plant design basis for ambient design conditions, site location and conditions, makeup
water conditions, and other preferred design conditions was established using documenta-
tion received by Idaho Power and by using published climatologic data. From ASHRAE
data, it was determined that an adequate design would be based on an ambient dry bulb
temperature of 80o , a wet bulb temperature of 60o , and at the site elevation of 3212 ft.
DESCRIPTION OF EXISTING SITE
The Evander Andrews Complex is a simple-cycle generating station that sits on an ll-acre
site at Mountain Home, Idaho. The site consists of two combustion turbines, a substation
store building, gas-metering compound, and control building.
approximately 3212 feet.
The site elevation is
Natural gas is supplied to the site on the site s northern boundary at pressures sufficient
for the combustion turbines without further compression. Water is supplied to the site via
deep wells that are capable of supplying up to 250 gpm. Water resources are minimal for
this site, which requires extensive water conservation.
The two combustion turbines are Siemens-Westinghouse 251 B12 units arranged in a
parallel configuration in an east-west direction. Each combustion turbine has a dry low
NOx combustor and is suitable for natural gas fuel only. Evaporative air inlet cooling is
installed on each turbine to limit capacity deterioration during high ambient temperature
Idaho Power Company
Preliminary Draft
3 -Sega Project No. 02-9999-
December 10, 2002
conditions.Continuous emISSIOns monitoring systems (CEMS) are used to monitor
emissions. Fin-fan coolers are used to cool lube oil for each of the combustion turbines,
Brush Electrical Machines in Loughborough, England produced the generators. They
operate at an approximate voltage of 12 kV. The nameplate voltage is 11.5 kVat 50 Hz.
However, the generator is driven at 60 Hz and the resulting operating voltage is approxi-
mately 12 kV.
Fire protection is currently installed onsite in accordance with the Fire Marshal's approval.
The fire protection system is capable of 500 gpm for 30 minutes. The system includes a
000-gallon reserve tank, electric pump, and full diesel backup pump. The well is capable
of supplying 200 gpm. Please note that the well is the sole source for site water. This
water is currently supplied for evaporative cooling, fire protection, and general service.
OPERATION DESIGN BASIS
The existing plant is utilized for peaking capacity. The combined-cycle plant under investi-
gation is a means by which Idaho Power Company can obtain additional capacity at
approved heat rate. For this reason, the basis of this conceptual plant design is seasonal
peaking capacity. The goal is to design this plant with minimal capital costs and maximum
additional capacity in order to get "more bang for the buck" This approach is warranted
because this plant is not base loaded. If the plant is under consideration for running nearer
to base load, higher capital costs would most likely be considered in order to increase the
overall efficiency of the plant.
REVIEW OF NEW HRSG DESIGN
In order to settle on an HRSG and steam cycle design, a number of design parameters were
reviewed. These include the number of pressures, high-pressure steam conditions, and the
amount of supplemental firing.
section.
Supplemental firing will be reviewed later within this
Idaho Power Company
Preliminary Draft
3 - 2 Sega Project No. 02-9999-
December 10, 2002
Number of Pressure Sections
The number of pressures in an HRSG is normally chosen based on several factors. One
factor is the mode by which normal operation will occur. For cases with high supplemental
firing in normal operation, fewer pressures will be included in the design. When exhaust
gas temperatures are increased with supplemental firing, the superheated steam section of
the HRSG will absorb the majority of the heat energy. Subsequent boiler sections will
absorb less heat and will produce little steam. For cases with little or no supplemental
firing in normal operation, more pressures will be included in the design. At lower exhaust
gas temperatures, the other boiler pressure sections absorb gas energy more efficiently.
Another factor is the design of the steam turbine. As the number of pressures increases
normally the steam turbine is designed for more inductions. For example, a triple-pressure
system may utilize the low-pressure boiler section of the HRSG to feed the de aerator and
use the intermediate and high-pressure boiler sections to supply steam to a dual induction
steam turbine. The capital costs for the steam turbine and piping systems can increase
substantially as the number of inductions increase.
Other factors in choosing the number of HRSG pressures are the desired plant efficiency
and equipment cost. For cases with little or no supplemental firing during normal opera-
tion, plant efficiency normally increases as the number of pressures increase. With an
increased number of pressures, more waste heat is recovered in a more efficient manner.
This is due to the increased heat transfer surface area in the HRSG. This translates
directly into an increased cost.
An HRSG with two pressures was selected for the plant under investigation. A single-
pressure HRSG would not have been sufficient to capture the amount of waste energy in
the exhaust gas stream. A dual-pressure HRSG was chosen because this limits total capital
costs. With this arrangement, supplemental firing can be utilized on a normal basis in a
manner which is more effective than for a triple-pressure HRSG.
Idaho Power Company
Preliminary Draft
3 - 3 Sega Project No. 02-9999-
December 10, 2002
High-pressure Stearn Conditions
The next step in evaluating the HRSG design was to determine high-pressure steam condi-
tions. These conditions have an effect on the HRSG tube properties, steam turbine design,
plant efficiency, and capital cost. Steam conditions were reviewed at 950 degrees over a
wide range of pressures from 800 psig to 1800 psig. Figure 3-1 illustrates the effect of
different high-pressure steam conditions on net heat rate. Figure 3-2 depicts the effect of
the different high-pressure steam conditions on net electrical output.
Figure 3-
Total Capital Costs and Net Heat Rate for Differing HP Design Steam Pressures
(Unfired Case)
555
550
545
540
535
~ 7 530III
~ 7 525
'iii
520
515
510
800 psi
505
1000 psig
500
$82,000 000 $84 000,000 $86 000 000 $88 000 000
Capital Costs ($)
Idaho Power Company
Preliminary Draft 3 - 4 Sega Project No. 02-9999-
December 10, 2002
Figure 3-
Total Capital Costs and Net Electrical Output for Differing HP Design Steam Pressures
(Unfired Case)
114 800
114 700 1000 psig
800 psig
1800 psig
114,600
~ 114 500
~ 114,4()0
7ii
~ 114 300
z 114,200
114 100
114,000
113,900
$82 000 000 $84 000000 $86 000 000 $88 000 000
Capital Costs ($)
Generally, as steam pressure increased, plant cost increased, plant efficiency decreased
and net electrical output decreased. The exception is found between 800 psig and 1000
pSlg.In this range , efficiency and net electrical output increased as the capital costs
increased. The incremental capacity and efficiency increase from 800 psig to 1000 psig
conditions was not considered justifiable due to the additional capital costs. Therefore
high-pressure steam conditions of 800 psig and 9500F were used for the conceptual design.
Supplemental Firing
Another stage in evaluating the HRSG design was to determine whether or not supplemen-
tal firing would be employed to develop additional electric capacity. Supplemental firing (or
duct firing) occurs by burning natural gas in exhaust gas that contains excess 02 to produce
additional steam in the HRSG. The exhaust gas temperature is increased significantly.
The increased exhaust gas energy is captured by the HRSG and translates into a greater
flow of high-pressure steam to the steam turbine , producing greater electrical output.
Idaho Power Company
Preliminary Draft 3 - 5 Sega Project No. 02-9999-
December 10, 2002
Supplemental firing can normally heat the exhaust gas to maximum temperatures of 1500
to 1600oF. HRSG price increases as the design firing temperatures increase. At higher
exhaust flow temperatures, the HRSG tube properties require enhanced metallurgy.
However, the cost of the duct burners is fairly low, so the overall increase in electrical
output justifies the costs in a peaking application.
REVIEW OF COOLING SYSTEMS
Three types of cooling systems were reviewed for this application: air-cooled condenser
surface condenser/cooling tower, and a wet/dry cooling system. Because water supply is
limited at the site, water conservation in the cooling system design is of the utmost impor-
tance. Each of these cooling systems was reviewed on the basis of capital costs, perform-
ance, and water consumption.For preliminary review, Sega reviewed the air-cooled
condenser option versus the surface condenser/cooling tower option. Upon completing this
preliminary review, Idaho Power Company concluded that the site water supply would be
insufficient for any type of wet cooling. Therefore, Sega evaluated the conceptual plant
design with an air-cooled condenser. The following discussion addresses the non-traditional
systems; air-cooled condensing and wet/dry cooling systems.
Air-cooled Condenser
Air-cooled condensers are normally used in plants that have limited water supply for
system makeup. Because water is at a premium, these sites must conserve water at all
costs. Air-cooled condensers condense steam without evaporating water into the atmos-
phere. Air-cooled condensers are essentially large fin-fan coolers in which steam is passed
through headers and then into finned tubes. Large forced draft fans blow ambient air over
the finned tubes. Steam condenses inside the tubing and the condensate passes into collec-
tion headers. Condensate is then pumped back into the cycle, except for minimal blowdown
as required to maintain cycle chemistry.
Idaho Power Company
Preliminary Draft
3 - 6 Sega Project No. 02-9999-
December 10, 2002
Air-cooled condensers have certain advantages and disadvantages. First, they require a
footprint and have high capital costs relative to evaporative cooling towers. Air-cooled
condensers typically cost more than 5 times the capital costs of a traditional surface
condenser and cooling tower combination. They also require nearly 20 times more plot area
and are nearly 4 times taller. Air-cooled condensers operate at a higher turbine back-
pressure than typical evaporative cooling systems. Increased backpressure reduces steam
turbine electrical output. However, for this case, it was determined that utilizing an air-
cooled condenser would prevent the flow of approximately 620 gpm required as makeup for
the traditional evaporative cooling tower. For sites with limited water supply, water
conservation is critical.
Surface Condenser and WetlDrv Cooling Tower
This configuration is normally seen in plants that require moderate water conservation or
evaporative cooling tower plume abatement measures. This configuration reduces makeup
water requirements. These systems are very similar to traditional wet cooling systems and
utilize a traditional surface condenser. The cooling tower is built much like a traditional
wet cooling system, except that fin tubes are affixed to the top of the cooling tower.
Essentially, this type of cooling tower combines the benefits of a fin-fan cooler and a wet
cooling tower, Condensate is passed through the finned tube sections. Air is passed over
these tubes to cool the condensate. Condensate is then directed through the evaporative
portion of the cooling tower. Because condensate temperature is lowered in the dry section
total evaporation is less than that of a traditional wet cooling tower. Reduction in water
consumption is the major advantage of this type of system.
Air around the fin-tubed portion of the cooling tower is heated by the cooling condensate
becoming relatively dry compared to saturated exhaust of the evaporative section. Because
the dry air combines with the humid air, the cooling tower plume is less visible, This is the
second major benefit of this type of cooling system.
Idaho Power Company
Preliminary Draft 3 - 7 Sega Project No. 02-9999-
December 10, 2002
Since this type of cooling system only reduces water consumption by around 10-20 percent
over a traditional wet tower, the water consumption was considered too high for this appli-
cation. Refer to Figure 3-3 for the water consumption of this type of cooling system in the
design configuration.
Figure 3-
Water Consumption of Cooling System Options
700 /
100
0 Cooling System
. Evaporative Cooling
ISJSteam Makeup
600
500
9 400
::J
300
200
Dry Air-cooled
Condenser
Wet-Dry Cooling
Tower
Wet Cooling Tower
PROPOSED PLANT DESIGN
For this application, a dual-pressure HRSG with supplemental firing is appropriate. Duct
burners will supplementary fire to approximately 1500o , which is normally considered the
upper limit of firing without using special technology. The HRSG would produce super-
heated steam at 800 psig and 950oF. An air-cooled condenser is utilized to minimize water
consumption.
Idaho Power Company
Preliminary Draft 3 - 8 Sega Project No. 02-9999-
December 10,2002
Integral de aerators are commonly built into HRSGs to de aerate condensate by using supply
steam from one of the HRSG's lower pressure sections. These de aerators are included in
the HRSG design and are normally more expensive than non-integral deaerators. Air-
cooled condensers provide substantial de aeration. Many combined-cycle plants that utilize
air-cooled condensers do not include integral HRSG de aerators due to the deaeration in the
air-cooled condenser. These installations have stand-alone deaerators located beneath the
air-cooled condenser. For this conceptual design, a stand-alone de aerator would be utilized.
A single pressure from the HRSG would not be required to supply the deaerator.
Steam turbine design is based on the backpressure of the cooling system and the inlet
steam conditions and flows. The steam turbine was sized for the maximum steam flow
from the HRSG. Because the design point is at 80oF and the design includes duct firing,
the maximum design steam flow is based on maximum duct firing at this temperature.
lower amounts of duct firing or higher ambient temperatures, the steam flow to the turbine
will be reduced. In order to allow for this variation in inlet steam conditions, a sliding-
pressure steam turbine would probably be utilized. Another consideration is the number of
steam admissions into the steam turbine. Because the HRSG is dual pressure and neither
pressure is dedicated to de aeration, the steam turbine would be dual-admission.
Idaho Power Company
Preliminary Draft
3 - 9 Sega Project No. 02-9999-
December 10, 2002
COMBINED-CYCLE PLANT PERFORMANCE
Based on the proposed plant design, a model was created using Thermoflow~ software to
simulate the plant's performance for various ambient conditions. The design basis for the
plant is summarized in Table 4-
Table 4-
Summary of Design Information
Site
Site Location Mountain Home, Idaho
Site Elevation 3212 feet
Ambient Conditions 80o F dry bulb, 60oF wet bulb
Equipment
Cooling System Dry Air-cooled Condenser
HRSG Design Information Dual-pressure, Duct Burner, 800 psig 950oF Steam
Steam Turbine Design Information Sliding Pressure, Dual Admission
Thermoflow~ software consists of two combustion turbine modeling programs. The first
program, GTPRO, develops a conceptual design and models the plant for the design condi-
tions. The second program, GTMASTER, uses the conceptual design from GTPRO and
models the performance for off-design conditions. Another program, PEACE, estimates the
capital costs and the equipment data associated with the plant design. This explanation is
in no way intended to promote Thermoflow
(g)
. It is intended only as an explanation of the
approach Sega took to arrive at the final results.
To reiterate, the conceptual design of this plant is "best bang for the buck" for seasonal
peaking. The plant design utilizes a dual-pressure HRSG. A duct burner is included that
can fire to temperatures of approximately 1500oF. During normal plant operation, the duct
burners would not be fired. The plant is designed to run most efficiently unfired. However
the steam turbine is oversized and the HRSG designed to support duct firing for additional
peaking capacity. The air-cooled condenser is sized accordingly.
Idaho Power Company
Preliminary Draft
4 -Sega Project No. 02-9999-
December 10, 2002
At the design point, as defined in Table 4-, net electrical output is approximately 111 MW
for unfired operations. This is a net increase of approximately 32 MW beyond simple-cycle
electrical output. By duct firing to 1500oF at these conditions, net electrical output rises to
148 MW for a net increase of approximately 69 MW. By duct firing, the additional gener-
ating capacity over that of the simple-cycle plant more than doubles. Table 4-2 summarizes
the performance outputs for the design point with and without supplementary firing.
Exhibits in the Appendix provide this information in greater detail.
Table 4-
Summary of Plant Performance
Unfired Fired to 1500o
Gross Electrical Output 116 500 kW 155 118 kW
Net Electrical Output 110,638 kW 148 356 kW
Auxiliary Power and Transformer Losses 862 kW 762 kW
Net Total Gas Turbine Electrical Output 940 kW 665 kW
Net Steam Turbine Electrical Output 560 kW 75,453 kW
Net Heat Rate 834 BTUlkWh 549 BTU/kWh
CHP Efficiency 43,56%39,91 %
Figure 4-1 illustrates expected plant performance over a range of loads and ambient
temperatures based on the results of GTMASTER modeling.
Idaho Power Company
Preliminary Draft
4 - 2 Sega Project No. 02-9999-
December 10, 2002
Figure 4-
Plant Performance Over a Range of Ambient Conditions (Without Supplementary Firing)
8100130000
125000
120000
::!
iii 115000
110000
Net Electrical Output
105000
100000
100
Ambient Dry Bulb Temperature (degrees F)
8000
7900 ~
e:.
7800 i
II:
:I:
7700 Z
7600
7500
GTPRO outputs approximate equipment performance and design information based on the
established conceptual design model. These outputs are meant to serve as a starting point
in approximating the type of equipment in the plant configuration. Vendors were contacted
to verify the equipment information as well as to confirm costs discussed in following
sections. Please note that vendor s preliminary designs vary from this conceptual design
somewhat, depending on the particular company. More Exact results would be anticipated
upon finalization of the design. The information provided by vendors is reasonable and
appropriate for use in this study.
Idaho Power Company
Preliminary Draft
4 - 3 Sega Project No. 02-9999-
December 10, 2002
CAPITAL COSTS
Costs were determined for the proposed plant design using Thermoflow(8) outputs and by
contacting vendors.Vendor budgetary pricing generally confirmed budgetary pricing
estimated by Thermoflow(8) for major pieces of equipment. These include the steam turbine
HRSGs, and the air-cooled condenser.
Budgetary proposals from vendors and are provided in the Appendix. The estimated capital
costs for the conceptual plant design are summarized in Table 5-1. A number of assump-
tions were made in developing plant costs. Major assumptions are listed under each of the
subsections following. Pricing assumes the combined-cycle conversion project would
accomplished on an engineer-procure-construct (EPC) basis, commencing engineering and
procurement during the first quarter of 2003. Commercial operations could commence
within 20 to 24 months from notice to proceed.
Table 5-
Probable Capital Costs
Project Cost Summary Estimated Cost
Specialized Equipment 379,488 USD
Other Equipment 956,360 USD
III Civil 876 653 USD
Mechanical 817 834 USD
Electrical 981 367 USD
Buildings & Structures 495 000 USD
VII Engineering & Plant Startup 654 565 USD
Subtotal - Contractor s Internal Cost 46,161,266 USD
Contractor s Price 53,214,658 USD
Owner s Soft & Miscellaneous Costs 789 328 USD
Total- Owner s Cost 58,003,987 USD
Incremental Net Plant Output 69.
Cost per kW - Contractor 771 USD / kW
Cost per kW - Owner 841 USD / kW
Idaho Power Company
Preliminary Draft 5 -Sega Project No. 02-9999-
December 10, 2002
PLANT LAYOUT
Figure 5-1 is a conceptual plant layout depicting the design basis for this study. It is
intended only as an illustration of the conceptual design and demonstrates that there
sufficient space on the existing site for the project.
Specialized EQuipment Assumptions
1. Pricing for the steam turbine package, HRSGs, and the air-cooled condenser
was verified with typical manufacturers of this equipment. Thermoflow(8)
outputs were adjusted accordingly to more accurately present these costs.
2. The combustion turbine installation is complete.
remediation, or demolition is required.
No modifications
3. Existing turbine exhaust stacks will be fitted with isolation dampers. A
zero leakage damper will be provided with the HRSG.
4. The steam turbine generator vendor will be selected from among Alstom
Dresser-Rand, General Electric, and Siemens-Westinghouse.
5. The HRSG will be supplied by Alstom, Deltak, Nooter Erikson, Rentech, or
V ogt- NEM.
6. The air-cooled condenser will be supplied by GEA, Hamon, or Marley
(Balcke Dur).
7. Due to the use of dry-type air-cooled condensing, steam jet ejectors were
utilized in lieu of mechanical vacuum pumps.
8. GEMS equipment pricing assumes the reuse of existing equipment. The
cost assumes an incremental addition for new equipment to be used in
combination with existing simple-cycle equipment.
9. Transmission voltage equipment pricing was adjusted to account for exist-
ing equipment. The cost assumes an incremental addition for one generator
step-up (GSU) transformer for the steam turbine. This cost also assumes an
incremental addition for one auxiliary transformer for the additional
combined-cycle equipment.
10. Generation voltage equipment pricing was provided for the added steam
turbine generator.
Idaho Power Company
Preliminary Draft
5 - 2 Sega Project No. 02-9999-
December 10, 2002
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Other Equipment Assumptions
1. Thermoflow(8) assumes that a demineralizer would be utilized for water
treatment. Based on our experience, Sega would expect that an RO system
would be utilized. A portable mixed bed would be used as a polisher and
would be regenerated off-site.
Civil Assumptions
1. The site is cleared and approximately leveled such that minimal grading
and drainage work would be necessary. Clearing and grubbing are not
included.
2. Spread footer foundations will be utilized assuming adequate subsurface
conditions for 2000-psf minimum design soil load bearing capability, No
allowance has been included for piers, piling, over-excavation, importing of
suitable soils or fill, structurally compacted back-fill, drying out soils in site
or any other remedies for unsuitable surface conditions. No allowance for
rock excavation, drilling, ripping, or blasting is included in the capital
budget.
3. Civil pricing was adjusted to reflect previous site work and grading, excava-
tion and backfill, concrete, and roads.
Buildings and Structures Assumptions
1. A bridge crane is not provided for steam turbine generator overhaul.
Removable roof panels with overhead access for truck-mounted hydraulic
cranes would be utilized. Capital budget is thereby reduced by approxi-
mately $150 000.
2. The steam turbine building enclosure would also house the control room
electrical equipment, water treatment system, and administrative areas in
a single structure with approximate dimensions approximately 70 feet by
110 feet. The building will be a slab-on-grade metal panel, pre-engineered
structure with no elevated slabs.
Idaho Power Company
Preliminary Draft
5 - 4 Sega Project No. 02-9999-
December 10, 2002
TABLE OF APPENDICES
APPENDIX A CAPITAL COSTS
Project Cost Summary
Specialized Equipment
Other Equipment
Civil
Mechanical
Electrical
Buildings
Engineering & Startup
Soft & Miscellaneous Costs
Cost Multipliers
APPENDIX B THERMOFLOW MODEL OUTPUTS
Unfired Case:
Heat Balance Diagram
Summary Text Output
Cooling System Schematic
HRSG Temperature Profile
Fired Case:
Heat Balance Diagram
Summary Text Output
Cooling System Schematic
HRSG Temperature Profile
APPENDIX C VENDOR PRICING SUMMARY SHEET
APPENDIX D VENDOR QUOTES
Air-cooled Condenser Quotes:
GEA
Harmon
Marley
Heat Recovery Steam Generator Quotes:
N ooter- Erikson
Rentech
Vogt-NEM
Steam Turbine Quotes:
Alstom
Dresser- Rand
Siemens Westinghouse
Idaho Power Company
Preliminary Draft
Sega Project No. 02-9999-
December 10, 2002
APPENDIX A
CAPIT AL COSTS
Idaho Power Company
Evander Andrews Complex
Combined Cycle Conversion Study
Table of Probable Capital Costs
Project Cost Summary Estimated Cost
Specialized Equipment 28,379,488 USD
Other Equipment 956,360 USD
III Civil 876,653 USD
Mechanical 817,834 USD
Electrical 981,367 USD
Buildings & Structures 495,000 USD
VII Engineering & Plant Startup 654 565 USD
Subtotal - Contractor s Internal Cost 46,161,266 USD
Contractor s Price 53,214,658 USD
Owner Soft & Miscellaneous Costs 789,328 USD
Total - Owner s Cost 58,003,987 USD
Incremental Net Plant Output 69.
Cost per kW - Contractor 771 USD / kW
Cost per kW - Owner 841 USD / kW
Estimated Cost
Total labor Hours
Avg. Weigted labor Rate
263,941
$28.
labor Costs
Material Costs
Commodities
$7,529,254
$35 201,205
$3,486 264
Appendix 1 of 7 12/10/2002
Idaho Power Company
Evander Andrews Complex
Combined Cycle Conversion Study
Quantity Est. Cost
I Specialized Equipment 28,379,488
1. Gas Turbine Package
Combustion Turbine Genset
Evaporative Cooling System
ElectricaVControVInstrumentation Package
Gas Fuel Package
Fuel Heating Package
Starting Package
Lube Oil Package wi Main, Auxiliary, & Emergency Pump
Compressor Water Wash System
High-voltage Generator
2. Steam Turbine Package 116,100
Turbine
Generator
Exhaust System
Electrical/ControVInstrumentation Package
Lube Oil Package wi Main, Auxiliary, & Emergency Pump
High-voltage Generator
Transportation to Site
3. Heat Recovery Boilers 600,000
Duct Burner & Burner Management System
Gas Turbine Exhaust Transition
Bypass Stack
Main Stack
Instrumentation
SCR & Aqueous Ammonia System
CO Catalytic Reactor for CO Reduction
Steam Vents & Water Drains
Non-return Valves
BIowdown Recovery System
Transportation to Site
4. Air-cooled Condenser 200,000
Tube Bundles
Fans, Gears, & Motors
Steam Duct & Condenser Piping
Turbine Exhaust Transition
Steam Jet Air Ejector
Condensate Receiver Tank
Support Structures
Transportation to Site
5. Continuous Emissions Monitoring System 350,000
Enclosures
Electronics, Display Units, Printers, & Sensors
Transportation to Site
6. Distributed Control System 732,900
Enclosures
Electronics, Display Units, Printers, & Sensors
Transportation to Site
Appendix 2 of?12/10/2002
Idaho Power Company
Evander Andrews Complex
Combined Cycle Conversion Study
7. Transmission Voltage Equipment 789,600
Transfonners
Circuit Breakers
Miscellaneous Equipment
Transportation to Site
8. Generating Voltage Equipment 590,888
Generator Buswork
Circuit Breakers
Current Limiting Reactors
Miscellaneous Equipment
Transportation to Site
Quantity Est. Cost
II Other Equipment 956,360
1. Pumps 885,245
lIP Feedwater Pump 420 840
IP Feedwater Pump 349 335
Condensate Forwarding Pump 13 , 524
Treated Water Pump 224
Demin Water Pump 670
Raw Water Pump 1 066
Raw Water Pump 2 066
Diesel Fire Pump 45,129
Electric Fire Pump 32,571
Jockey Fire Pump 709
ST+Generator Lube Oil Coolant Pump 111
2. Tanks 309,724
Hydrous Ammonia 28,392
Demineralized Water 59,430
Raw Water wi 2-hour Fire Water Storage 148 150
Neutralized Water 50,820
Acid Storage 466
Caustic Storage 466
3. Auxiliary Heat Exchangers 19,047
ST+Generator Lube Oil Fin Fan Cooler 19,047
4. Makeup Water Treatment System 614,460
5. Waste Water Treatment System 45,644
6. Stationllnstrument Air Compressors 41,559
7. General Plant Instrumentation 226,433
9. Low Voltage Equipment 673,470
Transfonners
Circuit Breakers
Switchgear
Motor Control Centers
Miscellaneous
10. Miscellaneous Equipment 140,779
Appendix 3 of?12/10/2002
Idaho Power Company
Evander Andrews Complex
Combined Cycle Conversion Study
Est. Cost
III Civil 876,653
1. Site Work 250,000
Site Clearinl!:
Culverts & Drainage
Erosion Control
Fencing, Controlled Access Gates
Finish Grading
Finish Landscaping
Material (Dirt, Sand, Stone)
Waste Material Removal
Obstacles R&R
2. Excavation & Backfill 58,026
Steam Turbine (1)007
Heat Recovery Boiler (2)32,020
Air-cooled Condenser 737
Underground Piping 832
Switchyard 720
Miscellaneous 710
3. Concrete 468,626
Steam Turbine (1)318 715
Heat Recovery Boiler (2)604 135
Air-cooled Condenser 219,105
Makeup Water Treatment System 196
Electrical Power Equipment 66,975
Pumps (7)18,436
Auxiliary Heat Exchangers 947
Station/Instrument Air Compressors (2)885
Tanks:567
Switchyard 14,238
Miscellaneous 167,428
4. Roads, Parking, Walkways 100,000
Pavement, Curbing, Striping
Lighting
Est. Cost
IV Mechanical 817,834
1. On-site Transportation & Rigging 476,736
2. Equipment Erection & Assembly 182,920
Steam Turbine Package 441,507
HRSG 235,923
Condenser 855 457
Makeup Water Treatment System 138,217
Electrical Power Equipment 187,072
Pumps 60,430
Auxiliary Heat Exchangers 732
Station/Instrument Air Compressors 156
Appendix 4 of?12/10/2002
Idaho Power Company
Evander Andrews Complex
Combined Cycle Conversion Study
Miscellaneous 255 426
3. Piping 915,268
High-pressure Steam 267 758
Intermediate-pressure Steam 45,551
Auxiliary Cooling Water 021
Feedwater 264,882
Other Water 238
Raw Water 39,141
Service Water 154 168
Fuel Gas 221,680
Lube Oil 20,439
Service Air 66,358
Vacuum Air 28,285
Ammonia 101
Boiler & Equipment Drain 337
Boiler Blowdown 727
Steam Blowoff 234 140
Fire Protection 121 632
Miscellaneous 147,811
4. Steel 242,910
Racks, Supports, Ladders, Walkways, Platforms 242 910
Est. Cost
V Electrical 981,367
1. Assembly & Wiring 981,367
Switchgear
Motor Control Centers 19,485
Feeders 268 096
Medium/Low-voltage Cable Bus 348,204
Cable Tray 149,232
General Plant Instrumentation 118 969
Generator to Step-up Transformer Bus 646
Transformers 805
Circuit Breakers 209
Miscellaneous 721
Appendix 5of7 12/10/2002
Idaho Power Company
Evander Andrews Complex
Combined Cycle Conversion Study
Area Est. Cost
VI Buildings 495,000
1, Turbine Hall, Including Control Room 400 420,000
2. Pump House 500 75,000
Est. Cost
VII Engineering & Startup 654,565
1. Engineering (10%)150,670
2, Startup 503,895
Est. Cost
VIII Soft & Miscellaneous Costs 11,842,721
1. Contractor s Soft Costs 053,393
Contingency:959,982
Profit:246 956
Permits, Licenses, Fees, Miscellaneous
Bonds and Insurance 461 614
Snare Parts & Materials
Contractor s Fee 384,841
2. Owner s Soft Costs 789,328
Permits, Licenses, Fees, Miscellaneous 064,295
Land Cost
Utility Connection Cost
Legal & Financial Costs 064,295
Interest During Construction 128,590
Spare Parts & Materials
Project Administration & Developer s Fee 532 148
Appendix 6 of?12/10/2002
Idaho Power Company
Evander Andrews Complex
Combined Cycle Conversion Study
Contractor Soft Costs Percentage, %
1. Contingency
Labor 15.
Specialized Equipment
Other Equipment
Commodities
2. Profit
Labor 20.
Specialized Equipment
Other Equipment
Commodities
3. Permits, Licenses, Fees, & Miscellaneous
4. Bonds and Insurance
5. Spare Parts and Materials
6. Contractors Fee
Owner s Soft Costs
1. Permits, Licenses, Fees, & Miscellaneous
2. Land Cost
3. Utility Connection Cost
4, Legal and Financial Costs
5, Interest During Construction
6. Spare Parts & Materials
7, Project Administration & Developer s Fee
Appendix 7 of7 12/10/2002
APPENDIX B
THERMOFLOW MODEL OUTPUTS
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1282 10-30-2002 15: 26: 52 file=C: /Documents and Settings/nninemire/Desktop/EXPERIMENTAL DRY 150
Page
Steam Property Formulation: Thermoflow - STQUIK
SYSTEM SUMMARY
Plant Configuration: GT, HRSG, and condensing non-reheat ST
--- - ------ ------ ---- - ---------------- --------- ------- -- ----
Power Output kWg gen. term. net LHV Heat Rate BTU/kWhg gen. term. net Elect. Eff. LHV %g gen. term, net
-- - -- -- - -- -- - - - - -- -- - -- - - - - - -- - - ----------------
Gas Turbine (s)Steam Turbine (s)
Plant Total
79940
36560
116500
10843 31.47
110638 7440 7834 45,43.
-- - -- -- - -- - - - - - - - - - - - -- - -- -- - --- - -- - -- - - - -- - ---- - -- - - - -- - - - -- - - - -- - - - - -- -- - - - - --
PLANT EFFICIENCIES
(%)- - - -- -- - - - - -- - - - -- - - - --- - - - - -- -- - - - ----------------
PURPAeff.CHP (Total)eff.Power gen. eff. on
chargeable energy
Canadian Class 43
Heat Rate, BTU/kWh
- - -- -- - - - - - - - - - - - - -- - -- - -- - - -- -- - -- - -- - - - -- - - - -- - -- - - - - - -- - ---- - --- - -- -- -- - - - -
43.43.43.8255
- - - - -- - - - - - -- - - - - - -- - -- - - -- --- -- - -- --- - - - -- -- - - - - - - - - --- - - ----- --- -- - ---- - - - --
GT fuel HHV/LHV ratio: 1.1096 DB fuel HHV/LHV ratio: 1.1096
Total plant fuel HHV heat input / LHV heat input = 1.1096Fuel HHV chemical energy input: 281853 kWth : 961766 kBTU/hFuel LHV chemical energy input = 254010 kWth : 866757 kBTU/h
Total energy input (chemical LHV + ext. addn.) : 254010 kWth : 866757 kBTU/h
Energy chargeable to power: 254010 kWth: 866757 kBTU/h( 93.0% LHV alt. boiler)
GAS TURBINE PERFORMANCE (SW 251 B12)2 unit (s), operating g 100 % load
-------------
Gross power
output, kW
Gross LHV
eff., %
Gross LHV Heat
Rate BTU/kWh
per uni tTotal 39970
79940
31.47
31. 47
10843
10843
Exh. flow
kpph
1207
2413
Exh. temp.
deg. F
-- - - -- - - - - - - - - - - -- - - - - - - -- - - - - - -- --- - - - - - -- - - - - - - --
961
961
- - - - - --- -- - - - --- -- - - - -- - - - - - - - - -- - - -- --------------
Fuel chemical HHV per gas turbine: 140926 kWth : 480883 kBTU/h
Fuel chemical LHV per gas turbine: 127005 kWth : 433379 kBTU/h
if'
Page
STEAM CYCLE PERFORMANCE
-- - --- - --- - - - - - - - - - - - -- - - - - - - - - -- -- - ---- - - - - -- - - - -- --- - --- - -- - - - -- - -- -- - - - - - - ---
HRSG
eft, %
Gross power
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Internal gross
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Overall elect
eff, %
Net process heat outputkWth kBTU /h
- - - --- - - - - - - - -- - - - - - - - - - - - ---- -- - -- - -- - - - -- - - - - - - -- - -- - - -- - - - - - - - --- - - - - - - - - - ---
76,36560 29.22.48
-- - -- - - - - - - - - - - - - - - - - - - - - - - -- - --- -- - - - - - - - - - - -- - - -- -- - -- ---- - -- - - - - - - - - - - - - - - -
No. of steam turbine uni t (s) = 1
Fuel chemical HHV to duct burners = 0 kWth, = 0 kBTU/h
Fuel chemical LHV to duct burners = 0 kWth, = 0 kBTU/h
DB fuel chemical LHV + HRSG inlet sens. heat = 162626 kWth = 554929 kBTU/h
Net process heat output = 0 % of total output
PLANT AUXILIARIES (kW)
- - - - -- - - - - - - - -- - - - -- - - - - - - -- -- - - - -- - - - - - - -- - -- - - - - - -- - - -- - - -- -- - -- -- - - - - - - -- - - --
Gas Turbine Auxiliaries Steam Cycle Auxiliaries
- - - -- -- - -- -- - - - - - - - - -- - - - - ---- - -- ---- - ----- --- - - - -- -- - - - -- - -- -- - - - - - - -- - -- - - - ---
Fuel
compo
Sup.fan Elect.chlr Other
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pumps
ACCfans fans Other
SC aux.
- - - -- -- - - - - - - - - - - - - - - - - - - - - - - - - - - -- - -- - - - - -- -- -- - - - -- -- - -- - - - --- -- - - - - - - - - - - - ---
191 523 3388
- - - - - -- - -- - - - - - - - -- - - - - - - - - - - - - ---- -- - -- - - - - -- - - - - - - - -- - - - - - - -- - - - - - - -- - - - - - - -
Constant plant auxiliary load = 0 kW
HVAC = 20 kW, Lights = 40 kW
Additional auxiliaries from PEACE running motor/load list = 984 kW
Misc. plant auxiliaries = 58.25 kW
Program estimated overall plant auxiliaries = 5279 kW
Transformer losses = 582.5 kW, Total aux. & transformer losses = 5862 kW
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GT MASTER 10.1 Nathan Ninemire
1282 12-06-2002 12:34:18 file=C:/Documents a.. .XPERIMENTAL DRY 1500 2 GTM
Steam Property Formulation: Thermoflow - STQUIK
SYSTEM SUMMARY
Plant Configuration: GT, HRSG, and condensing non-reheat ST
--- - - -- - ----- --- --- -- - - - - - --- - - ----- ---- ----- - - - ----- -- --- ----- ---- -- -- - -- -- - ---
Power Output kWg gen. term. net LHV Heat Rate BTU / kWhg gen. term. net
Elect. Eff. LHV %g gen. term. net
- - - -- ----- --- --- --- - -------- -- ----- ------ --- -- --- -- - - - - -- -- -- --- --- ---
Gas Turbine (s)
Steam Turbine (s)
Plant Total
79665
75452
155118
10880 31. 36
148356 8176 8549 41. 73 39.
--- ----- -- -- - --- - --- - - - ----- -- - --------- - -- - ---- - ------------ --- --- ----
PLANT EFFICIENCIES
( %)- - - - - - - - - - - - - - - - - - - - - - - - - -- - --- - - - - - - - -- - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - -- - - - --
PURPAeff.CHP (Total)eff.Power gen. eff. on
chargeable energy
Canadian Class 43
Heat Rate, BTU/kWh
- - - - - - - --- -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - -- - - - - - - -- - - - - - - - - - - - -
39.39.39.9073
--- ----- ---- - ----- -- -- --- -- ---- ---- -- -- - ----- -- ----------- ---- - -- ----
GT fuel HHV/LHV ratio = 1.1096 DB fuel HHV/LHV ratio = 1.1096
Total plant fuel HHV heat input / LHV heat input = 1,1096Fuel HHV chemical energy input = 412430 kWth = 1407335 kBTU/h
Fuel LHV chemical energy input = 371688 kWth = 1268311 kBTU/h
Total energy input (chemical LHV + ext. addn.) = 371688 kWth = 1268311 kBTU/h
Energy chargeable to power= 371688 kWth= 1268311 kBTU/h( 93.0% LHV alt. boiler)
GAS TURBINE PERFORMANCE (SW 251 B12)2 unit (s), operating g 100 % load
-------------- - - - -- - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - --
Gross power
output, kW
Gross LHV
eff., %
Gross LHV Heat
Rate BTU/kWh
Exh. flow
kpph
Exh. temp.
deg. F
- - - -- ----- --- - - - ----- -- - ------- -- ---- -- -- - ------------------
per uni tTotal 39833
79665
31. 36
31.
10880
10880
1207
2413
962
962
----------------- ----------- -- -- - -- - - - -- --- ------------------
Fuel chemical HHV per gas turbine = 140926 kWth = 480883 kBTU/h
Fuel chemical LHV per gas turbine = 127005 kWth = 433379 kBTU/h
Page
STEAM CYCLE PERFORMANCE
------- --------- - --- - -- -- - - ---- --- - - -- --- - - ----- -- - ----- -- - - - - - - -- - ---- - -- -- - - --
HRSG
eff, %
Gross power
output, kW
Internal gross
elect. eft., %
Overall elect
eff, %
Net process heat outputkWth kBTU/h
-- -- - -- - -- -- - - - -- - -- - - - ---- - -- - - - -- - -- -- - --- - --- - - - -- --- ------- - -- --- -- - -- --- ---
87.75452 30.26.
--- -- -- - - --- --- - ---- - -- -- - - --- -------- -- - -- -- - -- ----- - ---- --- -- - -- --- ----- --- ---
No. of steam turbine unit(s) = 1
Fuel chemical HHV to duct burners = 130578 kWth, = 445570 kBTU/h
Fuel chemical LHV to duct burners = 117678 kWth, = 401554 kBTU/h
DB fuel chemical LHV + HRSG inlet sens. heat = 280584 kWth = 957436
Net process heat output = 0 % of total output
kBTU/h
PLANT AUXILIARIES (kW)
------- -- - -- -- - ----- - ---- ------ --- - --- -- ---- - --- - -- -- --- ----- -- - ----- ----- --- ---
Gas Turbine Auxiliaries Steam Cycle Auxiliaries
- - - - - - - - -- - - - - - - - - - - - - - -- - - - - - - -- - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - - - - - - - - -
Fuel
compo
Sup.fan Elect.chlr Other
GT aux.
Feed
pumps
ACCfans fans Other
SC aux.
- - - - --- - - - -- - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - -- - - --
191 1113 3485
----- -- - -- --- - ------- - --- ----- - --- - - ---- -------- -- ------------- - ------------- ---
Constant plant auxiliary load = 0 kW
HVAC = 20 kW, Lights = 40 kW
Additional auxiliaries from PEACE running motor/load list = 984 kW
Misc. plant auxiliaries = 77.56 kW
Program estimated overall plant auxiliaries = 5986 kW
Transformer losses = 775.6 kW, Total aux. & transformer losses = 6761 kW
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GEA Power Cooling
Systems, Inc.Thermal and Energy
Technology Division
ALL DRY AIR-COOLED CONDENSER
Budgetary Information
Date:
Company:
Project:
Contact:
Phone No,
11/7/02
Sega
Idaho Power Company Evander Andrews Complex
Chris Rogers / Nathan Ninemire
913-681-2881
Ref, No,
Fax No,913-681-8475
(tQ fi(J~~~~r Q~si
Steam Flow
Q~sel~J:tr "
. '
610,8 308,kpph kpph92.4% 93.
64" HgA 2,66" HgA
800
QaselI
610,8 kpph
Steam Quality
Steam Turbine Backpressure
ACC Inlet Air Temperature
Site Elevation
Noise Level (fY 400 feet from the ACC Perimeter
93,
56" HgA
95O
61 dBA
3200'
60 dBA
No. of Bays
No, of Fan Modules/Bay
Fan Diameter
Plot Area (W x L)
Fan Deck Height
Overall ACC Height
Fan Shaft Power (Total)
Motor Rating
Main Steam Duct Diameter
32 ft,
113 ft, x 189 ft.
41 ft.
81 ft.
1880 kW
200 hp
13 ft.
32 ft.
117 ft. 156 ft.
40 ft.
81 ft.
1460 kW
200 hp
11 ft.
1I!i !J.
g~! '
I Jjf~~ DIj~.Jl~)Jl,Budget Price I $7,200 000 I $6,300 000
Note: The budget
p.!
ice isbfised on all material and equipfQeQt delivered to the site (DDU)
~ern~l;J(~.
The ACC designs for Case I and Case III were identical when completed, As such, they are presented
as one design above. Case II's design required less heat exchanger surface area to handle the duty so
the ACC is smaller than what is required for Case I and III.
The ACC drawing provided in Sega s transmittal would be less efficient and far more costly. Although
the designs above are budgetary, the were based on an optimization of cost (supply, construction, and
electrical), control, maintenance, freeze protection, and performance,
HAMON DRY COOLING
BUDGET PROPOSAL
SEGA INC.
FOR THE SUPPLY OF
AIR-COOLED STEAM CONDENSER
FOR
Idaho Power Company
(Sega Project No - 02-9999-05)
PROPOSAL HD - 0648
HAMON DRY COOLING division
HAMON COOLING TOWERS
HAMON CORPORA TE PLAZA
58 EAST MAIN STREET
SOMERVILLE
NJ 08876 USA
TEL. [phone]
FAX [phone]
MAIL toby.athron(g)hamon.com
:J:
Ref:
HAMON DRY COOLING
Contents
SCOPE OF SUPPLY ............................................................................................................
ENGINEERING SCOPE OF SUPPLY. ....... .....
......................., ....... ...... ..... .......... ,.......... ,..........
MATERIAL SCOPE OF SUPPLY .,...................................................,...............,."...",.............1.3 SCOPE OF ERECTION AND ERECTION SERVICES
...,...............,.................. ,......,......,...,..,.....
Erection......""
,., '.....",.."., '."..".""'.'" ,.. ,.,..", ,.... .........",.."" ...""......, .......", ,., ,....." ,..
Erection Supervision."..
........ ...,.., ...,. ....., ,..., ,.... "'."""""""'.""'.""'.' ..",."...".. ,......,.
COMMERCIAL PROPOSAL .............................................................................................
PRlCING """""""""'"
,... ,......... ..... .......... ....,.. .......,..,...,..... .........,..' ... ................ ..,.............
A CC.".."...
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DELIVERY TIME AND SCHEDULE.. ......,..... ................, ,....'.
.........".....'.......,...", ,...., ,.........,.
TERMS OF PAYMENT '....., ..... .....
..............., .........,'..' ,.. ,..... .....".........,....."............... ....... ,...
ENCLOSURES ...................................................................................................................... 7
3.2
DATA SHEET.,..........,......,.,..........."........,. ,..",....."..",.,.,.........,.....,............,..,....",............
GA ..., ....,..,'... .......
......................,. ..... ............ .... ,... '.. ..,.................. .......,................ ..,......".
Idaho Power, Evander Andrews Complex
Sega Ine - Hamon Ref. HD0648 Rev
11/07/02
HAMON DRY COOLING
SCOPE OF SUPPLY
Engineering Scope of Supply
The engineering scope includes the supply of the following documents, calculations
drawings and procedures:
Item
Thermal data sheets, equipment data sheets and unit performance
curves
General Arrangement Drawing
Foundation Loading Diagram
Civil design of all concrete supports
Piping and Instrument Drawing
Functional description of condenser control complete with alarm
setpoints, graphic display recommendations and control logic
Mechanical design with calculations of pressure parts and steel
structure
Detail engineering and drafting
Requisitioning
Procurement
Inspection and expediting of sub-suppliers
Manufacturer s databooks
Erection procedure
Site air test procedure
Steam cleaning procedure
Operating and maintenance manuals
Performance test procedure
Material Scope of Supply
Hamon Others
The material scope of supply includes the manufacturing, inspection, testing and packing of the
following materials.. Unless otherwise specified all items listed are located within the condenser
and main stream duct plots. Please note that other items can be quoted as optional extra s upon
your request.
Item
Turbine Exhaust duct from turbine exhaust to the steam distribution
manifold (60 ft assumed).
Steam duct support saddles
Ref: Idaho Power, Evander Andrews Complex
Sega Inc - Hamon Ref. HD0648 Rev
Hamon Others
11/07/02
HAMON DRY COOLING
Concrete duct supports
Steam distribution manifold including expansion joints and
inspection ports.
Balancing line from main steam duct to condensate collector
Finned Tube Bundles.
Galvanized mild steel ACC support structure from grade to fan deck
Fan deck complete with intermediate and external walkways
A' Frame bundle support structure including beam for manual
hoists, partition walls with doors and air seals.
Access and maintenance platforms , complete with toe-plate knee
and handrails and hot-dip galvanized grating or checkered plate
including one cage ladder in compliance with OSHA requirements.
One staircase to fan deck elevation.
Rupture disk assemblies, sized for 100% design flow.
Steam-condensate manifold within the condenser plot.
Condensate drain lines within the condenser plot.
Air take-off lines within condenser plot.
Fans, Gearboxes, motors & anti-vibration switches
Galvanized mild steel fan ring and FRP fan inlet bell complete with
fan screen
I x 100% Vacuum Pump for Hogging duty
2 x 100% Steam Jet Air Ejector for Holding duty
Interconnecting pipe work:
Condensate collectors to condensate tank
Air take off lines to vacuum equipment
Drain pot pumps to condensate tank
Windwall around periphery of ACC from fan deck to top of tube
bundles.
Local instruments, sensors and transmitters necessary for operation
and control ofthe air-cooled condenser.
Condensate tank with one de-aerator dome and supporting structure.
Isolating valves for winterization
2 x 100% horizontal type drain pot pumps
Commissioning spares
All embedded steelwork
Bypass assembly including pressure reducing valve and de-
superheating water spray ring
Lighting system
Finish painting
Cable trays and cables
Trace heating and insulation
Operating spares
Control system
Motor starters
Any items not expressly mentioned above
Ref: Idaho Power, Evander Andrews Complex
Sega Inc - Hamon Ref. HD0648 Rev
11/07/02
Scope of Erection and Erection Services
1.3.Erection
Erection is not offered as part of this proposal.
1.3.Erection Supervision
Hamon can provide an erection supervisor on a monthly basis.
Ref: Idaho Power, Evander Andrews Complex
Sega Inc - Hamon Ref. HD0648 Rev
HAMON DRY COOLING
11/07/02
HAMON DRY COOLING
COMMERCIAL PROPOSAL
Pricing
1.1 ACe
Our material cost for the scope of supply defined in Section I delivered to site, amounts to:
450 000................................ .net
(Six Million, Four Hundred & Fifty Thousand Dollars)
Delivery Time and Schedule
The first delivery to site would be 9 months from order placement. Subsequent deliveries would
be coordinated to complement your erection schedule.
Terms of Payment
10% as down payment after signed and effective contract
10% at sending of main arrangement drawings
25% at reception in our workshop of the raw material
55% Staged payments proportional to the amount of equipment delivered to site
Ref: Idaho Power, Evander Andrews Complex
Sega Inc - Hamon Ref. HD0648 Rev
11/07/02
HAMON DRY COOLING
ENCLOSURES
Data Sheet
DESIGN DATA
Steam Flow Rate
Turbine Back Pressure
Steam Wetness
Steam Enthal
Atmos heric Pressure
Air Intake Tern erature
MinIMax Air Tern erature
Noise Level
610 800 lb/hr
82 Psia
85 %
1044.3 BTU/lb
3212 ft
80 O
0 / 105 o
~ 85 dB A 3 ft
CONDENSER LAYOUT DATA DESIGN
Heat Exchanged 167,5 MW
Number of Modules
Arrangement (number of streets)3 x 3
Columns size ground level (W xL)120' 00" x 136' 04"
Fan deck level 47' 07"
Maximum height (including manifold)94' 10"
Bundles/module
Tube/bundle
Fan diameter 34 ft
Consumer fan power-motor ends 1682 Hp Total
Ref: Idaho Power, Evander Andrews Complex
Sega Inc - Hamon Ref. HD0648 Rev
11/07/02
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NOV 04 2002 12: 10PM HP LASER JET 3200 p. 1
JIImw~'~tl
1j!f.;
:'
~ Marley
(~ ~~g
Ted1naICl/iea.J~"""..
Marley Cooling Tecl1nologies,lnc,
405 Reo Street. Suite 300
Tampa, FL 33609 USA
Phone: [phone]
Fax: [phone]
WI'M,marleycl,com
info(9)narteyct.com
D~t~:November 4, 2002 Mer Ret 02-260-0313-193
.. .....
To:Sega, Inc.E~Mall r crogers~segainc.com
Stilwell, KS Fax N.!! :.nninemire~segainc.com
Mr. Chris Rogers
Afu!l1tion~"Vice President Frortl~Ralph W. WyndrumMr. Nathan Ninemire
Mechanical Enaineer
SJ;jijJpct:
. Air Cooled Condenser
IPC Evander Andrews CCPP Conversion Study Idaho
10'4
Dear Chris and Nathan
Jeff has for\Narded to me your revised ACe design conditions for this study. We note that you are now
interested in one design, We are pleased to support your project study efforts. Utilizing our proposal of
October 21, 2002 as a basis, please find attached our budgetary proposal for your review and comment.
As per the three(3) cases that you have indicated, your case 3 (800 , Unfired) is the controlling design
case. Based upon the Ace design meeting this case, the operation for the other cases will be readily
achieved, providing either reduced backpressure or reduced fan power.
We trust that the provided information supports your immediate needs. I look forward to speaking with
you to see if our design selection is in line with your expectations and to assist you in your proposal effort,
Please feel free to call me if you have any questions regarding our ACC proposal.
Sincerely,
Marley Cooling Technologies, Inc.
~~~
Ralph W. Wyndrum III, P.
Manager Dry Cooling
IW'fnd ru ce ra mic-c;t. rom
co:, GS, Jeff Meyer
NOV 04 2002 12: 10PM HP LASER JET 3200
fl!lll!limm~s.
Marl"llir CooIIngT~hlllJbu~'
,=, ,~~~"....
Ace, DESIGN CON'DIf:fON
Case 1
R~lng
"Fi re,~J;C aM"
610,800
044
168.
5.40
212
',..
~otal Exhaust:Steam Flow.
ExhaustS~ram Enth~lpy
Thermal :Coriaensing, DUty
Turbine -ExJi:BustPressli~e
Inlet Air Dry Bulb Temperature
Site Elevation
Ib
Btu lib
MWt
in. HgA
..,......
CiSe2 "
Rating"
Pii'ed::C~'i
610 800
064
169.
212
'c:~~;:
,p'~~'
ign
" ,
Vo.fired"
308,100
045
87.
212
Case'
' ,
AC:C DES'IGN 'SELECTION Design'
l4nfired"
N~,ri:iber,of Modules
Modl,lle'Arrangement
, forced -draft, roof-type
Number of Streets
Mod~les per Street
Plot Arrangement
Unit length 152
Unit Width 110
--- -
Unjtfl~ight
D'r,ive Equipment
Number of Drive Tra:il'iS
Fan Diameter (Forced ;Q~aff)
Mat(jr.-Si;ze 200/50
FarlF'ietd~ound 'Pressure Level ~ 400.dBa 64 dBa
from ~ce Perim'eter (AII'Fans,Full)
Total Design Fan Powe'r'(~'T. (All Fans Full)730
NOV 04 2002 12: 10PM HP LASERJET 3200
MARLEY COOLINGTECH NaLDOISa Cho.ro.cterlstlcs
of' AirCooled
S-teo.M Condenser
PRDJ.IPe IDAHO STUDY
02-260-0313-193
NAMEI SEGA
DATEI 11-04-EOO2
(H\oI)1 97.= toO~
(" HgA)1
(lb/lb)1
(" HgA)'26.
CkW')1 1730,
r..ml~ ~ ():~...;1a;!!iB (""",,\II: ..I1iI..n1tjS J!;W$1..
Ai:r 1(:'..~~kII,tjj .::."n..~...."I"I'~" Cln:)lup
Released Hen
Design Turbine Back Pressure
St~o.l"'t Quo.lI-ty
Atl'IDspherlc Prl!ssure
DesIgn Toto,l FD." POW!;!!" Ii! M.
All f'o.ns 0. t full speed
The c:hD.rc.derls"tlcs are bo.sed on calculated do.ta
E'xdudlng wlncl and o"ther Interference faders,
.....
100
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NOV 04 2002 12: 10PM HP LASERJET 3200
.~~~~Jlr~I
MarleY
CooIk1gT~ies'
".....
Air Cooled Condenser PriceTerms: MCT Terms & Conditions (Available upon request)Price Basis: Budget (:t 10%)
Quotation Validity:
Material Delivery:
Payment:
About 28 weeks (starting) from Approval of Basic Engineering Documents
Progress Payments based on engineering and material deliverables, net 30
days.
. .. ..
$A.SE MATERIAL SCOPE.
Units
C~$e,
~ .. .
Design
Unflre'~W . .
FOB; DDP, Job Site, Idaho $
Imm~diate Job Site Unload of" Deliveries $ US
Optiona1 Componerits
BA$E 'SERVICE SCOPE OF SUPPLY
ACC:Mi:OHAMtCAL ERECTION ADVISOR
(Recommerlded in.the event meGhanicBl erection is perforrr1edby others)
Ace 'Me~HANICAL ERECTION
(1ypical'Non:Union' budge1ary.estimate.Actual price willvaJ)' dependIng
on Q(evaiUoo.D~lect aJ!Idl~onS)
ST:ART ..UP: &CaMM ISSI()NU~G'S ERVICE
TA*ES 0O1lES & f'EES
O",t$.ide USA
Wi'thi~'l.!SA
Import Duties and Fees
local; State, Federal or Other Taxes, Fees, Etc.
643,000
By Erection Contractor
$ US
$US
$US
$ US Included in Above Material Scope
$ US 000
15 Weeks
$ US 300,000
$ US 000
3 Weeks
$ US Included
$ US
$US
Included
Not Included
HEAT RECOVERY STEAM
GENERATOR QUOTES
~~, ~W' .ww. .~. ww . RA wwUwO..O'O w lUMrnlN~&nl~N~H ~UUllUU6
IE NO OTERI ERIKSEN
November 15, 2002
Sega, Inc.
16041 Fosler
Stilwel1. KS 66085-1000
Attention:Mr. Chris Rogers & Mr. Nathan Nincmire (i!) [phone]
Regarding:Idaho Power s Evander Andrews Complex
NE Proposal No, 1207-
Gentlemen,
Please find attached !hennaI performance and heating surface data sheets associated with
the updated heat balances you sent for our review on October 31.
Our budgetary price and delivery for these units as described in our October 24. 2002
letter to YOll remain applicable,
For further infonnation regarding Nooter/Eriksen s experience please feel free to call me
at [phone] or to visit our website at www.ne,cor)l
Very truly yours
CY-
Chris Kotowicz c-j
Sales Engineer
cc:T &K. C&N
Offices: 1509 Ocello Drive. Fenton, MO 63026. P.O. Box 66888. St. louis, MiS5ouri 63166-6888
Telephone: [phone] Fax: [phone] Email: sales(ine.com
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IE
NOOTERIERIKSEN
October 24, 2002
Scga, Inc.
16041 Foster
Stilwell, KS 66085-1000
Attention:Mr. Chris Rogers
Fax: [phone]
Ref:Idaho Power - Evander Andrews Complex
N/E Proposal 1207-
(2) SW 251 B12 HRSGs
Dear Chris:
We are pleased to submit budget pricing for the Evancter Andrews Complex HRSGs,
Base Price
Budget base price for two (2) Fired Heat Recovery Steam
Generator as described in the inquiry specification:500 000.
(Eight Million Five Hundred Thousand V,S. Dollars)
Ex Works
Budgetary price adder for freight for two (2) HRSG from the
manufacturing facility to the nearest rail siding (for rail
shipments) Or plant gate (for tI\lck shipments) to the site in
Mountain Home, Idaho:300 000.
This HRSG will be designed and fabricated in accordance with Section I of the ASME
Boiler and Pressure Vesse! Code.
The scope of supply of the HRSG is essentially complete from the combustion turbine
outlet flange through the exhaust stack including all of the required pressure parts
necessary to generate the desired steam production, interconnecting AS ME Section I
Code piping local to the boiler. boiler trim, ladders, platforms, and stairtower. Our
budget accounts for the SCR cata1yst systems, CO catalyst, duct burners, and bypass
diverter damper assemblies.
Offices: ,S09 Ocello Drive. Fenton. MO 63026. P.O. Box 66888, St. Louis, Missouri 63166-6888
Telephone: [phone] Fax: [phone] Email: sale~~ne,'om
Sega, I RC.
NtE Proposal 1207-
Page 2
Comment to Specification
No specification has been received for review, Further discussion wiJl be necessary in the
future to establish or confinn details,
Validity
As noted, this is a budgetary (indicative) price, We offer to fino up our pricing after
receiving additional information from Scga.
Delivery
Based upon present workload, General Arrangement Drawings (Plan and Elevation),
Foundation Loading Diagram, Foundation Base Plate Details and P&ID will be submitted
in ten to twelve (10-12) weeks after receipt of a purchase order and full release.
Based upon availability of materials and present shop conditions, shipment of major
components will be completed ten to thirteen (10-13) months after receipt of a purchase
order and a fuJl release to proceed with manufacturing.
This delivery schedule is contingent upon traditional lead-time of materials. CuTTently, a
partial release to purchase critical path materials may be required prior to full release of
the eqwpment.
Taxes
Sales, use, excise or other taxes, as well as duties or tariffs, are not included and are the
responsibility of the Purchaser,
Should you have any questions, please call me at 636-651-1107,
Yours very truly,
NOOTER/ERIKSEN, INC.
U-:-
Chris Kotowicz
Sales Engineer
cc: T&K
S:\2002\120742\Budgc:t Proposnl 2002-1 0-doc
.v. ~" v~. u~. V , ~... . n... v - v --- v'v-..-/
rnn Moo
INDUSTRIES
u.
........ .._-..:.' \"~ !\,~. .' \, ."~""'; ': ',.
.-I
......
November 21 2002
Sega, Inc.
16041 Foster
Stilwell, Kansas 66085-100
Attention:
Reference:
Mr. Nathan Ninemire
Idaho Power Company
Heat Recovery Steam Generator (HRSG) Equipment
Dear Mr. Ninemire:
Rentech Boiler Systems, Inc. is pleased to offer our budget price quotation for the supply of Two (2) Heat
Recovery Steam Generator systems for the referenced project.
II.
Thermal Performance
HRSG thermal performance data sheets are attached for your review.
HRSG System Scope of Supply
The HRSG system shall include the following equipment and services:
HRSG inlet duct with internal insulation and liner panels,
High pressure superheater assembly.
High pressure evaporator assembly.
High pressure economizer assembly.
IP superheater assembly.
IP evaporator assembly,
Combination IP/HP economizer assembly.
FW heater assembly.
High pressure steam drum with shop installed steam purification equipment to provide a
steam purity based on maintaining the minimum recommended ABMA drum water
concentrations.
IP steam drum with shop installed steam purification equipment to provide a steam purity
based on maintaining the minimum recommended ABMA drum water concentrations.
Natural gas fired duct burner assembly including burner management system.
Main stack to a total elevation of 100 feet above grade.
Field mounted instrumentation to include safety valves with silencers, steam drum water
columns , start-up vents with silencers, pressure gages , high pressure superheater
attemperator, main steam stop and non-return valves, thermocouples with wells and small
bore trim.
III.
5025 b. Business 20
ABILENE, TEXAS 79601 or
O. Box 5071 , Abilene, Texas 79608
915-672-3400 FAX [phone]
Platforms and ladders to provide access to instrumentation located on the steam drums and
main stack EPA ports.
Interconnecting piping between heat transfer sections.
Customer Supplied Equipment and Services
Expansion joints at turbine exhaust outlets.
Deaerator
Flash tank and drains.
External thermal insulation and lagging for piping, steam drums and stacks.
Sampling panel for sample coolers.
Start-up, testing and commissioning of the units.
Piping and sampling system for nitrogen blanketing, chemical dosing, alkaline boil-out and
chemical cleaning, Code isolation valves are supplied by Rentech Boiler Systems, Inc., per
ASME Section I.
Foundation design and installation, including anchor bolts, nuts and grout.
Heat tracing.
Steam/water analyzers,
Spare parts, beyond start-up spares.
All utilities required during installation and commissioning of the boiler.
Hydrostatic test of the boiler after erection.
Bailout, acid cleaning and steam blow of the HRSG systems.
Feedwater and condensate pumps and motors. Feedwater recirculation pumps and motors
on skids are not included.
Cooling water distribution piping.
Instrument piping and tubing.
Instrument service air.
All other necessary controls and field instruments , as required to complete the system , not
supplied as part of the Rentech Boiler Systems HRSG scope of supply and system,
C:\Documents and Settings\nninemire\Local Settings\Temporary Internet Files\OLK4\BudgetProposal,doc
All electrical wiring, conduit and cable trays, etc. required to complete the system.
)Ul) b. .tlusmess 20
ABll..ENE, TEXAS 79601 or
O. Box 5071 , Abilene, Texas 79608
915-672-3400 FAX [phone]
Steam and water piping outside the terminal points.
Motor starters and disconnects for all motors, including power wiring to motors,
Chemical feed system.
Final field paint.
IV. HRSG PricinQ Summary
.The budget pricing for the supply of two (2) HRSG system, as described within Section II, HRSG
System Scope of Supply, is: 000.000 USD
V. Clarifications
We have attempted to match your heat balances but noticed your heat balances include
significant pressure drop between HPS2 and HPS3. Our performance runs do not include that
pressure drop. Based on the steam pressure required at the steam turbine we would we estimate
that the HP boiler design pressure would be approx 1 000 psi.
The tube metallurgy shown on the following pages is preliminary.
The above pricing does not include local, state, sales or federal taxes, or taxes of similar nature.
We would like to thank you for allowing us to offer our service, and we look forward to the opportunity of
working with you, Should you have any questions concerning this budget proposal as submitted, please
do not hesitate to call me.
Very truly yours
Rentech Boiler Systems, Inc.
Kevin Slepicka
Senior Sales Engineer
HRSG Systems
Phone: [phone]
Fax: [phone]
Email: kslepicka (g) rentechboilers.com
C:\Documents and Settings\nninemire\Local Settings\Temporary Internet Files\OLK4\BudgetProposal,doc
5025 E. Business 20
ABILENE, TEXAS 79601 or
O. Box 5071 , Abilene, Texas 79608
915-672-3400 FAX [phone]
Section Tubes Nwnber Transverse Long.Arrangement TotalPerof Rows pi tch Pitch Heating
Row Surface(in)(in)(Sq.
Ft. )Superheater Staggered 40203
3 -Superhea ter Staggered 4624SuperheaterStaggered5171EvaporatorStaggered17305EvaporatorStaggered80406
7 -Economizer Staggered 28625SuperheaterStaggered4527EconomizerStaggered1503010-Evaporator Staggered 4020311-Economizer Staggered 4426812-Economizer Staggered 15509
Section Tube Tube Wall Tube
Thickness Material
(in)
(in)
Superhea ter 135 SA213 -T2 2Superheater135SA213 -T2 2Superheater135SA213 -T2 2Evaporator120SAl78-AEvaporator120SA178-A7-Economizer 1. 5 120 SA178-
Superhea ter 105 SA17 8-Economizer 1. 5 120 SA178-10-Evaporator 105 SA17 8-A
11-Economizer 1. 5 105 SA178-12-Economizer 1. 5 105 SA178-
Section Fin Type Fin Fin Fin Fin FinLengthPitchHeightThicknessMaterial
(in)(in)(ft)(#tin)Superheater Serrated 409SSSuperheaterBareSuperheaterSerrated375409SS
5 -Evaporator SerratedEvaporatorSerrated
Economizer Serra tedSuperheaterSerra ted 375EconomizerSerrated10-Evaporator Serrated
11-Economizer Serrated
12-Economizer Serrated
C:\Documents and Settings\nninemire\Local Settings\Temporary Internet Files\OLK4\BudgetProposal,doc
Rentech Boiler Systems, Inc.
Predicted Performance Summary
Case:
Total Heat Loss
Blowdown
GAS FLOW (lbm/hr)
Turbine Exhaust Flow
Duct Burner Fuel Flow
Total Flow Exiting HRSG
BURNER SUMMARY
Burner Fuel
Heat Input (LHV) , MMBtu/hr
Fuel HHV Btu/ IbmFuel LHV, Btu/ Ibm
Augmenting Air Flow, lbm/hr
Fuel
CH4
C2H6
C3H8
nC4HI0
iC4H10
nC5H12
iC5H12
Composition (By Volume)
90.00 % C6H1400 % 00 % 00 % CO200 % 00 % H2O00 % H2S
FLUE
CO2
H2O
GAS ANALYSIS (By Volume)
STEAM FLOW SUMMARY (lbm/hr)
Final Steam Flow
Spray Flow
Process Flow
Steam Drum Exi t Flow
Blowdown Flow
Feedwater Flow
Stand Alone Econ / FW HTR
PRESSURE SUMMARY (psia)
Steam Pressure at Exit PointEvaporator Outlet
5025 E. Business 20
ABll.ENE, TEXAS 79601 or
O. Box 5071 , Abilene, Texas 79608
915-672-3400 FAX [phone]
1. 0 %
1. 0 %
1206600
10212
1216812
Gas201.1
21817
19688
00 %
00 %
00 %
00 %
00 %
00 %
00 %
Exhaust Gas
98 %
72 %
74.36 %
14.04 %
90 %
After Firing
31 %
10,28 73,37 %
11.15 %
89 %
1 HP Blr 2 IP Blr 3 Comb Eco 4 F.HTR
295422 6946
1421
294001 6946
2970
296971 7016
303987 303987
862
918
294
305
C:\Docurnents and Settings\nninemire\Local Settings\Temporary Internet FiIes\OLK4\BudgetProposal,doc
""'!!i .
)02) b. Husmess 20
ABllENE, TEXAS 79601 or
O. Box 5071, Abilene, Texas 79608
915-672-3400 FAX [phone]
Rentech Boiler Systems Inc.
Predicted Performance Summary
Case:
TEMPERATURE PROFILE SUMMARY (F)
Gas Side Water/Stearn SideSectionGroupInlet Temp Outlet Temp Inlet Temp Outlet Temp
1 Superhea ter 958 948 933 949
2 Burner 948 1500Spray 314/943 933
3 Superheater 1500 1382 710 943
4 Superheater 1382 1260 534 710
5 Evaporator 1260 949 454 534
6 Evaporator 949 591 454 5347 Economizer 591 495 359 454
8 Superheater 495 494 419 490
9 Economizer 494 449 314 359
10 Evaporator 449 431 314 419
11 Economizer 431 292 174 314
12 Economizer 292 255 138 176
WATER/ STEAM SIDE PRESSURE DROP1 Superheater 1 9.3 Superheater 1 13.
4 Superheater 1 3.7 Economizer 1 8,8 Superheater 2 1.9 Economizer 1 3.11 Economizer 3 8.12 Economizer 4 3.
SUMMARY (psi)
Note:Pressure drops are for heat transfer sections only.
GAS SIDE PRESSURE DROP
1 Superheater 12 Burner
3 Superheater 1
4 Superheater 1
5 Evaporator 1
6 Evaporator 1
7 Economizer 1
8 Superheater 29 Economizer
10 Evaporator 2
11 Economizer 3
12 Economizer 4
SCR/CO Pressure Drop
Stack Pressure Drop
Misc. Pressure Drop
Total Draft Loss
SUMMARY (in. H2O)
1. 90
1.13
1. 50
1. 00
12.
C:\Documents and Settings\nninemire\Local Settings\Temporary Internet Files\OLK4\BudgetProposal,doc
Rentech Boiler Systems, Inc.
Predicted Performance Summary
Case:Case 2 - Fired
Total Heat Loss
Blowdown
GAS FLOW (lbm/hr)
Turbine Exhaust Flow
Duct Burner Fuel Flow
Total Flow Exiting HRSG
BURNER SUMMARY
Burner Fuel
Heat Input (LHV), MMBtu/hr
Fuel HHV, Btu/lbm
Fuel LHV, Btu/lbm
Augmenting Air Flow, lbm/hr
Composition (By Volume)
90.00 % C6H1400 % 00 % 00 % CO200 % 00 % H2O00 % H2S
Fuel
CH4
C2H6
C3H8
nC4H10
iC4H10
nC5H12
iC5H12
FLUE
CO2
H2O
GAS ANALYSIS (By Volume)
STEAM FLOW SUMMARY (lbm/hr)
Final Steam Flow
Spray Flow
Process Flow
Steam Drum Exit Flow
Blowdown Flow
Feedwater Flow
Stand Alone Econ / FW HTR
PRESSURE SUMMARY (psia)
Steam Pressure at Exit PointEvaporator Outlet
5025 E. Business 20
ABILENE, TEXAS 79601 or
O. Box 5071, Abilene, Texas 79608
915-672-3400 FAX [phone]
1. 0 %
1. 0 %
1200700
10099
1210799
Gas
198,
21817
19688
00 %
00 %
00 %
00 %
00 %
00 %
00 %
Exhaust Gas
98 %
63 %
74.42 %
14.07 %
90 %
After Firing
30 %
10.18 %
73.44 %
11.20 %
89 %
1 HP Blr 2 IP Blr 3 Comb Eco 4 F.HTR
295235 7399
876
294359 7399
2973
297332 7474
304806 304806
861
917
295
306
C:\Docurnents and Settings\nninemire\Local Settings\Temporary Internet Files\OLK4\BudgetProposal,doc
)VLJ b. J::msmess LV
ABll.ENE, TEXAS 79601 or
O. Box 5071 , Abilene, Texas 79608
915-672-3400 FAX [phone]
Rentech Boiler Systems, Inc.
Predicted Performance Summary
Case:Case 2 - Fired
TEMPERATURE PROFILE SUMMARY (F)
Gas Side Water/Steam SideSectionGroupInlet Temp Outlet Temp Inlet Temp Outlet Temp
1 Superheater 959 951 936 949
2 Burner 951 1500Spray 321/942 936
3 Superheater 1500 1381 709 942
4 Superheater 1381 1259 534 709
5 Evaporator 1259 947 456 534
6 Evaporator 947 589 456 534
7 Economizer 589 496 364 456
8 Superheater 496 495 419 491
9 Economizer 495 452 321 364
10 Evaporator 452 432 321 419
11 Economizer 432 301 190 321
12 Economizer 301 265 154 190
WATER/STEAM SIDE PRESSURE DROP1 Superheater 1 9.
3 Superheater 1 13.4 Superheater 1 3 . 397 Economizer 1 8.
8 Superhea ter 1 . 539 Economizer 1 3.11 Economizer 3 8.12 Economizer 4 3.
SUMMARY (psi)
Note:Pressure drops are for heat transfer sections only,
GAS SIDE PRESSURE DROP
1 Superheater 12 Burner
3 Superheater 1
4 Superheater 1
5 Evaporator 1
6 Evaporator 1
7 Economizer 1
8 Superhea ter
9 Economizer 1
10 Evaporator 211 Economizer 12 Economizer 4
SCR/CO Pressure Drop
Stack Pressure Drop
Misc. Pressure Drop
Total Draft Loss
SUMMARY (in, H2O)
1. 89
1.12
1.49
12.
C:\Docurnents and Settings\nninemire\Local Settings\Ternporary Internet Files\OLK4\BudgetProposal,doc
)UL) h. Business 20
ABILENE, TEXAS 79601 or
O. Box 5071 , Abilene, Texas 79608
915-672-3400 FAX [phone]
Rentech Boiler Systems, Inc.
Predicted Performance Summary
Case:Unfired
Total Heat Loss
Blowdown 1. 0 %
1. 0 %
GAS FLOW (lbm/hr)
Turbine Exhaus t Flow
Duct Burner Fuel Flow
Total Flow Exi ting HRSG
1200700
1200700
FLUE
CO2
H2O
GAS ANALYSIS (By Volume)Exhaust Gas
98 %
63 %
74.43 %
14.07 %
90 %
STEAM FLOW SUMMARY (lbm/hr)
Final Steam Flow
Spray Flow
Process Flow
Steam Drum Exi t Flow
Blowdown Flow
Feedwater Flow
Stand Alone Econ / FW HTR
1 HP Blr 2 IP Blr 3 Comb Eco 4 F.HTR13758217144
137582 17144
1390 173
138972 17317
156289 156289
PRESSURE SUMMARY (psia)
Steam Pressure at Exit PointEvaporator Outlet 620
657
176
202
C:\Documents and Settings\nninemire\Local Settings\Temporary Internet Files\OLK4\BudgetProposal,doc
Rentech Boiler Systems, Inc.
Predicted Performance Summary
Case:Unfired
TEMPERATURE PROFILE SUMMARY (F)
Gas SideInlet Temp Outlet Temp959 919
Section Group
1 Superheater 1Spray
3 Superheater 1
4 Superheater 1
5 Evapora tor
6 Evaporator 1
7 Economizer 1
8 Superheater 2
9 Economizer 1
10 Evaporator 211 Economizer 12 Economizer 4
WATER/STEAM SIDE PRESSURE
1 Superheater 1
3 Superheater 1
4 Superheater 17 Economizer
8 Superheater 2
9 Economizer 1
11 Economizer 3
12 Economizer 4
Note:
919
884
840
696
523
488
485
460
411
323
884
840
696
523
488
485
460
411
323
277
)u:.zS b, Business 20
ABILENE, TEXAS 79601 or
O. Box 5071 , Abilene, Texas 79608
915-672-3400 FAX [phone]
Water/Steam
Inlet Temp
762
321/762
627
496
487
487
419
383
367
367
199
111
Pressure drops are for heat transfer sections only,
GAS SIDE PRESSURE DROP
1 Superheater 12 Burner
3 Superheater 1
4 Superheater 1
5 Evapora tor
6 Evaporator 1
7 Economizer 1
8 Superheater 2
9 Economizer 110 Evaporator 11 Economizer 12 Economizer
SCR/CO Pressure Drop
Stack Pressure Drop
Misc. Pressure Drop
Total Draft Loss
DROP
1. 78
16.
SUMMARY (psi)
SUMMARY (in. H2O)
1. 85
1. 09
1. 49
11,
Side
Outlet Temp
926
762
762
627
496
496
487
483
419
383
367
199
C:\Documents and Settings\nninernire\Local Settings\Temporary Internet FiIes\OLK4\BudgetProposal,doc
~-i:- ~eM
Date: November II, 2002
Sega Inc.
Mr. Chris R. Rogers
Vice President
O. Box 1000
Stilwell, Kansas 66085.100
Fax [phone]
# of pages 16
Subject: Idaho Power Company
Evander Andrews Complex
HRSG Budget proposal
Your reference: No, 02-9999-
Dear Mr, Rogers
Reference is made to your inquiry dated October 31 , 2002. We have the pleasure of submitting our budget quotation
for the supply of two Natural Circulation I ieat Recovery Steam Generators for the Evander Andrews Project. This
quotation is based upon the IIsswnptions and terms and conditions mentioned hereafter, and upon the specifical1ons
data and information provided by you,
For your review we have included our HRSG configuration as well as our HRSG performance tables. We have
reviewed the dimensions as indicated in the request for proposal and marked up the dimensions that will change as a
consequence of our design.
We deviated from the specified design in one significant area. The feed-water was fed directly into the de-aerator
which is supplied with pegging steam from the IP drum. As an approach temperature of at least 10 F is required to
make tbe de-aerator function, there was no real purpose for a pre-beater. Also, with the higher oxygen content of
non-deaearated water, it might have been required to make the pre-heater from stainless steel. In order to make the
cycle efficient, we also dropped the pressure in the de-aerator further.
Note it may not be necessary to include a dc-aerator in the cycle, as usually, condensers perform this role as well,
This document com.... ..I'on..."oo ,hat " "","cbI 101 us, of 'h. "",","".ol 0' "'oy '0 wIUo:b iI is IddrtssH oncI ...y .D.,ain ..I.",...io. Ih. " pn.;lq;o.1. 'D.fod=iol, ancInnl1pl from diKlo'Ufe uncIcT "I'Pbclble 10... II We ..- 01 llus documen, ~ nol ,he inr~ ,ccipiCftl or ,he emploY"' or .gent r_nsibIe for "'ncrin& "" documcnl 10 the
""ended rocip;cv. you ue heRby nolir.od lbo. "Y diunn...,;.., cli.mbu1Ion. Dr COPYW\K DflNs 'DmmunX:llion .. ..nrlly ~bited ,,",hou. ...nllen ..,lIoriz.,..n &"m VDE,.NEt.!
Inco'~"'IIIed.
~~~"-l:.-I.et:'f Vogt-NEM, Incorporated - Louisville, Kentucky, USA
Document Title:
SKtlon TItle:
SKllon Rev. Date:
Budget quole Doeument bsue Date:
Vogt-NEM Rtf. ~o.
Section Page No.
:-';ovemb... II . 2002
209J
~-t:- r:feM
BUDGET PRICE LIST
Base Units - Otv. 2 Unites)Amount
Natural Circulation. Dual Pressure, Non-Reheat (Fired) HRSG US$250 000
Field Service - Ot\'. 2 Unil(s)
Construction, stan-up and commissionins;! advisor (8 man-monrns)US$Included
Burner Start-up Advisor Included
SCR Start-up Advisor USS Included
OPTIONAL BUDGET PRICING
Amount
600 000
PRICE CONDITIONS & VALIDITY
Proposal and Price is valid for 90 days from the submittal date of this proposal.
Prices are for delivery DDP site (as derIDed by INCOTERMS. 2000), not offioaded for all truck
transported items, and DDP nearest railway siding, not offioaded for pressure pan modulcs and HP
drum.
The SeHer retains the right to withdraw this proposal at any time before fonnal acceptance by
Purchaser upon approval in writing by an officer ofVogt-Nl:M lnc,
The Seller will, in good faith, negotiate mutually agreeable terms and conditions prior to Notice to
Proceed,
Prices are based on the use of free world-wide sourcing ofbolh labor and components.
Prices are exclusive of alllaxes, with the exception of import duties.
Prices are exclusive of bank guarantees, confirmations, and letters of credit.
Thd """""en' co...... ..romu..... "'" .. u.1mdcd for "'" or the in4Md1ool or "'.J 10 ""'"=h ;, is oddr.,..ccI "" ""'1 con'... ..fo.....ion Ihlo .. privilq;ccI. confidcn,.I, one!.....,po &om duelosur. under """heoble: low. II ,lie ruder ohhis doc...... is BOt ,he inlrnded rccipocnl or the empID)'tt 01 "enl '"pons;ble rD' dc:~"';"I:.he docurncnIlO ,lie'DIm4od """"enl, )'OU ... t.ereby lIO,ifiod 11001 any dis,.""n.,ioD, clislributoon. or copy;.; ohlU:r c""""",""..ion ;, "nclly prnlUbilerl";lhn", wnnen o.,ho",.,;o. /no.. Vo,..NEM.IncorporOlod
~~
.n.-f:.- NeM.n .... Vogt-NEM, Incorporatcd - Louisville. Kentucky, USA
Document Title:
Section Title:
SectlOD Rev. Date:
Budget quote Document "sue Dale:
Vogt-NEM Rer. No.
Section Page ='10,
~ovembcr It. 2002
2093
~~~-~eM
We sincerely hope that this quotation is satisfactory 10 you and will provide a sufficient basis for further discussion
and negotiation, In case of any questions. please do not hesitate to contact us.
Vogt-NEM, !nc,
Jan Willem Cieremans.
Account Manager
Tel [phone]
Fax [phone]
Cell 502-819-9520
e-mail icieremans~vo~-nem.com
ATIACHMENTS:
SCOPE OF SUPPLY
TERMINAL POINTS
EQUIPMENT DELIVERY SCHEDULE IN WEEKS AFTER NTP
HRSG PERFORMANCE
HRSG DESIGN
TYPICAL WEIGHTS AND DIMENSIO~ TABLE
cc. Mr. Bob Hesler The Hesler Co. 913-642-1040
This doe."", cono.... info......oo lhat io inlmdod lor ...e of lhe ..clivodual or ...;Iy 10 w!uch " is oddms.d and may COOl';" ""o.....ioo lhas is ""viq:ed. ...lid.",w, andnmlpl from diKloturc.""" applicable law. III'" ,eader of 11m dOCUIMII is nol the ."mdcd RC1J'O"" or the ""plo)ff or a,enl rapo",iblt for deli\"""g lilt docwncol 10 lhe--ended Iccipicnl, you ~ h.,.,", notified lhot '"'Y d..........;.", dislriboJliou. or coPY"!; ofllm eommurucalion .. tlric1ly I".MOlcd wnboul Wlin... lolbori.."oo from VoC,.NEM.!neorpar..
~~cj*- Me~Vogt-NEM, Incorporated - Louisville, Kentucky, USA
Documenl Tille:
Seelion TIlle:
Seclion Rev. Dale:
Budget quole Doculnl'nl Issue Dale:
Vogl-NEM Ref. No.
Section rage No.
November 11.2002
2093
~-t:- r:4eM
SCOPE OF SUPPLY
J. J.Scope Table
HRSG Scope of Supply Furnished By Furnished By Option Nol
HRSG SdJer Others Applicable
Item Description
Heat Transfer Components and Casines
II.Steam Drums and InteJ:!1'al Deaerator
HP Steam Drums wlImernals
IP Steam Drums w/lmemals
Integral Deaerator
III.Inlet Duct
Gas Turbine Outlet Expansion Joint
Inlet Duct
Silencin~ Equipment
IV.Outlet Stack & Transition Duct
Outlet Duct and Stack Including Bottom
Drain
Outlet Stack FAA LiRhtinR
Outlet Stack Silencer
Stack Damper
Platforms, Stairs, Ladders, and
Handrails
VI.HRSG Pipin,R (up to Terminal PointS)
VII.Duct Burner System
Fuel Pressure Reducing Station to 30
PSifl
Th;, doc........ c.o...... ;"fonnel"" II"" 0 ..m&d In. ... ollh. in40viduaJ or .."ty to ",hi1:b iI is ood may rncnain info.....io. lho, is P~. confidcnlw, &n4.....pI from dioclot... WIder oppIicob!e low 111M ruder ol,h;, documer" 0 nol tho: inlmdcd ncipinrI or ,"" nnpJoyee or I~cnl mpo..ibk lor rkh.cring ," docum"" 10 Ih,immdcdnc;p..... you.. hereby notified duo Illy """"""'0', d;'lnbul.... .. c.p~ ofthis c........atia. is..riclly pro.b,.d ",.ho., ..";'Im I.'no.....io. 6.m V.&I-SEM
!ncO'PO"""'.
~o~-t.-1:feM Vogt-NEM, Incorporatcd - Louisvillc, Kentucky, USA
Document Till.:
Section TIll.:
Section Rev. Dale:
Budget qUOle Document Issue Date:
Vogt-NEM Ref. No,
Section Page No.
November It. 2002
209J
~~~-~eM
HRSG Scope of Supply Furnished By hrnished By Option Not
HRSG Seller OIhcn Applkablt
IX,CO Catalyst System
Catalyst Spool Piece Only (throwaway)
SCR Catalyst System
Ammonia Storage Tank and Delivery
System
SCR Catalyst housing
Catalyst support system
Catalyst
SCR supply skid (aqueous anunonia)
Injeclion Rrid
Interconnecting piping
Xl.Exhaust Bypass System wi Dampcr
XII,Blowdown Systcm
XIII,Boiler Feed System
XIII,Boiler Recirculation System
XIV.Soolblower System
Valves
HRSG Vents & Drains
Steam Outlet Valves (NRV)
Steam Outlet Valves (Stop Valves)
Feedwater inlet Valves (stop and check)
Feedwater Control valves
HP steam Let Down Station (HP steam
to Cold Reheat)
Start Up Vents
Blowdown Valves
T1w cIoc...- tONo,'" .,fanno"". "'"' ;. ..codoc! roo use of the indMduol or CUlly 10 whKJI . " 1ddros,,11 and may com... ..Ionna"'. ,hac is ~04. coofidcmw. ....s
ru",pc ~om dd,:1o,Ule ...der appt;coble law. If lbe ",ad.. of Ihis documen' IS DO' the ;.Icnded 'Kip;", Of 1M .",ploytt or '~'" ,..pons,bOr 10f dehvenn& lbe doc"mcnt 10 ,he
inlended ruipieN, yo"...e hereby .otified INt..y diueminotion. dIs'ribKioo,.f eopl'inl; .f"'" cormnonic....n is "'."'1 p'olubotrd ""thou!........ ,",horizoI... &0111 Yo"""cM,
Incorpor...d.~~~*.~eM
..
.... Vogt-NEM, IncOIporated - LouIsVIlle, Kentucky, USA
Document Tille:
Section TItle:
Section Rev, Date:
Budget QUOIt Document Issue Dale:
Vogl-NEM Rd. No.
Section Pagt No.
l'iovembcr II. 2002
2093
.o~-t:-~e~
HRSG Scope of Supply urnishtd By Furnished By Option Not
HRSG Sdler 01 hers Applicable
XVI.SRV and Silencer Systems
XVII.Instrumentation
Pressure GawRes..
Temperature Indicators and Elements
Steam Drum Water Gauge Glasses
Steam Drum Electronic Water Level
Indicators
XVIII,Control and Control Elements
Temperature Transminers
Pressure Transmitters
Drum Level Transmitters
Steam Flow Nozzles
Feedwater Flow Nozzles
Attemperator Flow Nozzle
Flow Transmitters
HP Superheater Atternperator
Reheater Attemperator
XIx.Miscellaneous
Freeze Protection
Flow Model Test
. 3.Start-up Spare Parts
Special Tools
Foundation Base Plates
Foundation Anchor Bolts
",., do.u............oim infomun"", rIw is intended r... .... of 110. in4viduo! 01 cnI;ly 10 which il IS odd......s oM "'1 ",nl';" mfo",,",ion ,1101 ;. priy~ed. .onfldm,w, Uld
"cmpI &om dDcloout. ""oIer oppI""bI. I,~.. If ,h.
.-
of,bis documcnl .. nOI 110. inlended "";pm' orth. "'P\oY" '" ,~"" rnpo..iblc: for ddiutting ,... c!onomcnl 00 ",..,'ended ra:op;...t. )'Ou..t...ot.y DOl/lied 'hlt...y disomunol/on , dnlribu,1OI1. or .opying of Ibis ,ormlwUc:8Iion is ,.,x,ly p",hibded ..who","';"... luthoriz.ooion &om Vogl-NEMInc""",..o..!.
~o~*-~eM Vogt-NEM, Incorporated - Louisville, Kentucky, USA
Document Title::
Sc:ctlon Title:
Stc:llon Rev. Dote:
Budget quote Document hsue Dale:
Vogl-NE:YI Ref. No.
Scc:tlon Pale No.
November II , 2002
209J
~-t:- ~eM
TERML"\AL POINTS
DuctWork
Inlet Flange of the DiveI1er damper.
Outlet of the HRSG outlet stack and HRSG bypass stack.
PiDinl!
All large bore piping (greater than 2" IPS) shall be supplied to the field in spools. The majority of large bore
pipe spools will be cut to length with both ends weld prepped,
All small bore piping (2" and smaJler) shall be provided in random lengths for field installation- All small bore
piping shall be routed to 3' above grade where possible.
Main Water Terminal Points
InJet connection of the economizer shall tenninate approximately 3 feet above grade located on the same side as the
boiler fcedwater pump.
2.4,Main Steam Terminal Poinl"
The outlet connection of the steam piping shall tencinate at an approximate elevation of 40 feet near the Top of the
HRSG, located OD the side of the HRSG,
Attem era
The attemperator water lines will terminate at the inlet connection of the automatic block valve on the anemperation
device approximately 3 feet above grade,
Drain Valves. Vents. Steam and Water Samplin2 and Intermittent BJowdown
Lines shall be double valved with the first valve close connected to the source and with the second valve terminating
approximately 2 feet above grade located on a common side of the HRSG unless otherwise noted, All vent lines shall
be double valved with the rust valve close connected to the source and with the second valve tenninating 8 feet
above the platform elevation. or on the inlet ductWork. Individual economizer harp vents may be vented through the
drum,
This documen, comllN ",funnlllon lhal " .-oded IOf 1M 01 ,he InCiMdvoI or on\;\y to wllich iI A 04drcssed one! may CDn".. inlorma',on l\wl . priV1!o,;od. eonfidnuoal, and
CAmp' '0.. dAdo,wc under applicable Is.. " ,he r.adcr 01 II", docum.., io nollhe ..,ended roc;pienl or lho employee or '~cnI rcsl"'n.iNe I.. IIchvcrins ,he 1Iocu""", 10 ,be
."ended TK;pim1, you arc hc\'cby noulled IhallllY disscnunoIion, disfribo1;on, 01 c.op)inc o!lhis c.ommuDicOlion ;, ..riclly pro'ubi'cd ..;IOOul wrillen ,.,OOnu.;". from V",,-NEM.
IncolJlO"'cd.
~~~~-~eM Vogt-NEM, Incorporated - Louisville. Kentucky, USA
Document Tllte:
Section Til~:
SKtlon Rev. Dale:
Budgel quole Document Issue Date:
Vogl-NEM Ref. No.
Seclion rage No.
November II. 2002
2093
c:. ~-i:- ~eM
Continuous Blowdown
Continuous blowdown line shall be double valved with rlIst valve dose connected to the source and the second valve
shall tenninate approximately 5 feet above grade close to the HRSG,
Chemical Feed & Nitro2en Blanketing Connections
", .
Inlet connections shall be double valved and tenninate close connected to the steam drums,
SCR T enninal Points
The SCR will tenninate at the slcid within 25' of the HRSG.
Burner Terminal Point~
The Burner will terminate at the slcid within 25' of the HRSG,
"Tn;' doc,"""" CI"II..... ",formatio. 111M ;, iDlcndod fol ... of,~ indilOduaJ or ",oy 10 wlUcb i. " aM-ftSe:I 8nd may ron..", ",fonO8lloo tha. ,. p'MlqjO1!, CO"lMIemial, 8nd"""PI from dUclos... un"" opplicablo low. If,~ road.. or Ibis cIocumom is nOI lhe ;"'cndo:I rocip.... or the cqJloyoc or 8I:mI r"POlISlbIc fo, ckt"CfV1j; ,"" d........, 10 the..,mdod 'C"'I""", you an he.by nolifiod ,bar "'1 cIio"""",;O,," d;'lrilNtion, or copyin& oflb;. co.......;",,"," 0 slnclly prohiboIC4 ""haul wnur. o..'honur"",1rotn Vo,:l.NEMIncolJ)O"""
~o~-t.-~eM Vogt-NEM, Incorporated - Louisville, Kentucky, USA
Document Title:
Section Title:
Section Re". nale:
Budget quOit Document 1s5Ue Dale: November II. 2002
Vogt-:'iEM Ref, No.
. \'.
2093
Section PaKe 1"0.: 8
~ ~~-
~eM
EQillPMENT DELIVERY SCHEDL'LE IN WEEKS AFfER NTP
Major Comoonent Unit I Unit 2
'Foundation Plates
Boiler Steel - Goal PostS & Transverse Beams
Complete Deliverv of Modules
Inlet Duct Panels, SCR Housing & Burner Outlet duct
Drum
Platforms, Ladders & Stairs
LarRe Bore Pinin2
Stack
SCR catalyst Before start-up Before start-up.
CONDITIONS OF EQUIPMENT DELIVERY
Complete shipment schedule and delivery sequence will be agreed upon before the time an order is
placed, Bundle delivery is anticipated to be or 'cold to hot'.
Dates are based on delivery of the last piece of a specific component unless otherwise stated.
No storage costs have been included in this offer for Seller s supplier equipment. All the costs
(unloading, loading, transportation to & ITom the storage area location, storage and other fees,
insurance, provisions for weather protection, etc.) associated with the storage initiated, requested or
caused by the Buyer for any Seller supplied equipment on or around the site or elsewhere will be paid
by the Buyer. The schedule impact of this storage time shall be equally reflected on the overall
project schedule.
All deliveries will be made by rail or truck. Heavy duty rail cars are to be unloaded wilhin 48 hours of
arrival, Heavy haul trucks are to be unloaded within 2 hours of arrival. Permit load and regular truck
deliveries are 10 be unloaded on the same day of arrival, Delays in unloading leading 10 demuITage
charges shall be borne by the Buyer.
Deliveries being receIved from overseas may have multiple unit equipment together and therefore may
be delivered to the site at the same time, If this is not acceptable, then the storage provisions set out
above will apply,
Seller reserves the nght to deliver up to 4 weeks earlier than the scheduled date given prior notice by
the Seller.
This doc........ COni';'" mfonnal"a ,ho, ;, ..mded ro, use of ,... mvld.aJ 0' "'.Y 10 ,,1UCI1 i1 u .MMscd ond m.y can,';" inro.....ion lba' is pnui!eicd , co.'-"""'IoI. ...d
"""'1" m.m disdos." omdcr app!iClblc law If lbe tCldcr of .h~ doc.""", " nol the ..cnMd tCC;p;..1 or lhe cmpIoy.. 0' 'I!"" r..pon,;bIc lOr dcbrtrin,; ,Ito docum",' 10 .he
inlcndcd reci......, )'0' .... "",.by IIOIificd WI lilY d"""",......... tIutn"b..lio.. 0' copyin~ oftta. c.""""",,"ion;, suictly ,"olu"\);,ed ...haul "",I,,, lU,ho,;,,"'n hom V.~,.s~M.
Incorpo"'cd.
~~~*-
NeM
...
.... Vogt-NEM. Incorporated - Louisville, Kentucky, USA
Document Title:
Section Title:
Sedlon Rev. Dale:
Budgel quOlc Oocumenllssue Dale:
Vogl-NEM Ref. No.
Section Page No.
November 11 2002
2093
~~~-
~eM
HRSG PERFORMANCE
.0. Expected Pe~formance Data
...
Customer:Service:Sega Idaha Power Co~pa~y SW 2~:-B12 2C93A CT/JW 07.NOV.Case Unfired/80FAmb/32\R2 A. 01. 001
Exhaust Gas Flow (lbs/hr) 120660CGas-side pressure drop (inwc) :2. ~Burner output (MMBtu/hr) 0,
Exhaust Gas Temperat~re IF)Total Losses
(%)
~ower Heating Value (Btullb)
957
21534
Inlet Gas Constituents (by we) CO2 4.63 ~20 4.9C N2 73.39 AInlet Gas Constituents (by va:) CO2 2.98 H2O 7 - 72 ~2 7~, 36 A 1. 2 6 02 15.90 02 14,
Outlet Flow(!bs/hr)Temp,
(F)
Press,
(psia)App r, Te:r,
(f)
P::Jch Point
(=)
Blow-Down
('A)
I P
136968 94623907 472115 126
HP, IP data a~e those
DA flow refers to the
6:1 13,10 13,
i5, a
after ~RVs
dlL'IIp steam flow
25.
13.
99.
HPDS 1 Sp~ay flow (lbs/hI:)35~IF)
I---------------Steam/wate~ S i de- --- --
---- -----
I-Gas Side-I
Section Flow Temperature Cu:y ':'emperature(lbs/hr)(f)(:-!M3tu/l-.r)(F)
OUt Out
HPSHl 136968 926 946
;',
:'2 956 952HPDSI136968926926952952HPSH2136968874926952940HPSH3136968750874940910BRNRI0, CO 910 910HPSH~136968 494 750 23.910 8377 -HPEVl 5914 4 482 495 43,837 702HPEV269165482 ..95 5~. 96 702 540HPEV386594824 9~540 520lC.HPECI 136968 434 482 520 49611.IPSHI 23907 366 472 1. 52 496 492:2.HPEC2 136968 355 434 11.492 45/113.:PEVI 12259 355 368 :0.454 42014.IPEV2 12702 355 36e 1: . ~6 420 38415.I PEV3 1244 355 368 1. 08 384 38016.I PECI 163174 3:3 353 380 358I PEC2 163174 246 313 11.28 358 32118.IPEC3 163174 126 24 E 19.321 257
-------
220.
This cia".,..", cone.... ..rormaoion lbat n ..mdaI for .... of lhe .,d,.;.!"') or """'Y 10 wluch i, . oddon=l and ""y con.... informal;"n 0"-' is pivilq:ocI, confidc:nlial. ",d..cmpo from disdo.ufc ...der opplicablc: low. If ,... .OIder Dr II.. clac",""", ;, not ,h. ""mcIcd ""'P"'" or Ihc anplo)"'" or "1;"'" =ponsibl, for detiv.m,: ,he doc"""", 10 lhe;nlorded "";p;.m, YO"'. no,;ficd ,hM Illy m....nm..ioo, _,ioD. or coPYD'l Dr.... c"...."""",ion ;",nelly I"Otubilrd ",nho., '""'I'" ..,ho"""ion &om VOB,.NEMIncorporalN
~~~*-t:l.eM Vogt-NEM, Incorporated - LouisviJle, Kentucky, USA
Document Tille:
SKtion TIlle:
SecHon Rev. Dale:
Budget quole Documcnllssue Dale:
Vogt-i'iEM Ref. No.
Section Page No,
November J I , 2002
2093
~ ~*-
~eM
... Expected Perfo~ance Jata ..0
Customer:Service:Sega Idaha Power Co~pany
Case Fired/80FAmb/32%RH
sw 251-B:2 2093A C7/Yn C7 .NOV .
p',
:J2, CO2
Exhaust Gas Flow (lbs/hrl 120660CGas-side pressure drop (inwc) 13.Burner outp~t (MMB~/h~) 20e.: 5
Exha~st Gas remperat~re (:)
Tota: Losses
(%)
~ower Heating Val~e (Bt~/lb)
958
21534
Inlet Gas Constituents (by w~) CO2 4.63 H2O 4,90 N2 73.39 AInlet Gas Co~s~ituen~s (by vol) CO2 2.98 ~20 7 72 N2 74.36 A
1.26 02 15.90 02 :4.04
Outlet Flow(lbs/hr)Temp.
:FI
Press.
Ipsia)
Appr. Te~p
(P)
?inch ?oin~
IF)
Slow-Down
(% )
303138 9477783 517115 !48
H?, IP data are those
DA flow refers to the
833 8~,291 83.4 9,
after NRVs
dcrnp steam flow
4J.
99,
HPDSI Spray flow 634 (lbs/hr) 333 :FI
1----
---- --- --
--Steam/water S ide------- -------- I I-Gas Side-I
Section Flow Tempera ture Jc:ty Temperature(lbs/hr)IF:(MMBtu/l'.r)IF)
Out Out
HPSHl 303138 942 948 1.19 957 954
HPDS1 303138 947 943 95..954
HPSH2 302504 944 947 954 951
HPSH3 3C2504 940 944 951 949
3RNR1 949 1500
....
HPSH4 302504 540 94::1 84.1500 126:
HPEV1 137039 459 541 103,1261 96:
HPEV2 148110 459 SoD 1~1. 58 961 624
HPEV3 17354 459 54 13.624 58410.HPECI 302504 39"459 20.584 520J 1.IPSHI 7783 415 ~17 520 51812.HPEC2 302504 333 397 20,518 45413.IPEVI 4946 332 416 454 44014.IPEV2 5015 332 416 4. ~2 440 42615.:::PEV3 648 332 4: 6 426 424
:: 6.IPECI 313747 27C 331 J 9.424 36117.IPEC2 3:3747 209 270 19.361 30e18.IPEC3 31370 148 209 J 9.300 238
--------
424,
Tha Ooe"",.., c:oaum Wlfonna"on lbal iI;
....-
for USt of ,'" lIIdi.ocIuaJ 01 ."t.y 10 ..Inch n .. oddmscd and INY co",oi. inlo"""lIo. lhat is pri'~ed. eonfid",u"', and..empt &om cIioclo,.", .nder opplXobIr law" If lhe lead.. orm;, documcnI ;, no,..", ...ended rmpoenl or lhe emPoyer or 81:"" ...po..ible for dtbWftVl\: "" doc........ 10 .he..ended lce;per")'Ou an: hereby ""titled .hat any diucmination, dDtribohon, or COPY"'c ofm;, CO""""""IIO. a III"'1y pt'olllbottd....ho.. wnll'" 8""""""'io. hom Vo..,NEM'""o"",wed.
~~~*-~eM Vogt-NEM, Incorporated - Louisville, Kentucky, USA
Documenl Tille:
Section Tille:
Sedlon Rev. Date:
Budget quole Doeumenllsslle Date:
Vogt-NEM Ref. No.
SedloR Page xo.
November II. 2002
2093
~~~-~e~
... Expected Performance Data ...
Cus::ome::-:Service:Sega Idaha Power Company
:ase F:red/95FAmb/1:%RH
SW 251-312 2093A CT/JW " KOV" 02
O3,O03
Exhaust Gas Flow 11bs/h::-) 12~0100
Gas-side press~re drop :i~wc) 12.Bur:1er ou::put (MMBw/hi:) 198.
Exhaust Gas Temperature (~)
Tota 1 Losses
(%)
Lower Heating Value :Btu/ lb)
959
21534
Inle~ Gas Consti::~ents :by wt) CO2 4.61 H2O 4.8~ N2 73.43 AInle:: Gas Con~titJents (by vo:) CO2 2.98 H2O 1.63 N2 7~.43 A
2602 15,0, 90 02 H, C 7
Outlet low Temp,Press.Appr.Temp Pinch poin:Blow-Down
(lbs/h::-)
(:)
Ipsia)IF):F)
(\:
302361 832 79.43.0, CO
BESS 511 291 78.
: 15 162 99,
HP.IP data are t~ose after NRVsflowrefers to the dump steam flow
HFDSI Spray flow 808 (1bs/hr)338 IF)
1---
- - -- -
-------Steam/water Side---------------I Gas S~de-I
Section Flow Teopera 1:11re Juty Temperature(lbs/hr)IF)(MMBtu/t-.(F)
i::-:Out.Out
HPSH1 302367 941 948 1. 32 958 954
HPDSI 302361 941 942 954 954
HPSI!2 301559 944 948 954 952
HPSH3 301559 940 944 952 949
ERNR:O. CO 949 1500
H?SH4 301559 540 940 84.500 1261
H?EV:136827 461 540 102.l2E 1 960
HPEV2 141508 461 540 110.9EO 624
H?EV3 17224 461 540 12.624 583
10.HPECI 301558 400 461 2~.583 520
11.IPS!".l 8656 415 517 ~. 57 520 ':.19:2.H PEC2 301558 338 400 19.513 456
13.IPEV1 5192 337 416 456 441
14.I PEV2 5268 337 416 441 426
15.I PEV J 678 337 416 426 424
16.IPECI 313504 279 336 18.424 364
17.IPEC2 313534 220 278 lB. 25 364 306
19.IPEC3 31350~:&3 220 IB.3::6 243
--------
419.
This documcnc co...... inlo""."o. ,.... " ""ended lor us. olllle lIIdi\"CluoJ Of .."il)' 10,,1Uc;h it is od&.....,...d...y co..... ..Io""",,on "'" "pnvilqod. confida"...l ond
..anpl 1r01O d&lo...r. ,noIn appbc.obl. 18.. II ,lie ICOda 01 ,h. doc"",... is 1IO111Ie ..,eodcd rocipicnl or IIIe anpI.,.. 01 '~"" "'po"",blt lor dcl".......: ,"" doc....... 10 "'"
inrooded rocipiml, ~o. ~ baoby ooUr..d II." ..y cId........;"n, &',"..."on. or copyins ollhis co"""""io. is "rialy prohibJlod,.;,oo", ....,en ..,ho""",on from Vo~18E!IoI
lotorpo...od.
,""","~~*-t'.e~ Vogt-NEM.lncorporated - Louisville, Kentucky, USA
Document Tille:
Section Tille::
Sec:tion Rev. I)ate:
Budget quole Document blue Dale:
Vogl-NEM Ref. No.
Sec:llon Page I'D.
:-.Iovcmbcr 11.2002
2093
~~~-~eM
HRSG DESIGN
... Mecha~ica: Data 0.0
Jsto:ner:Service:Sega Idaha Power Co~pany SW 251-312 2093A CT/JW 07.NOV.Case U~fired/80FAmb/32\Rn A.Ol,OO:
Inlet Gas Flow (lbs/~r)
Exit Gas :low (lbs/hr)1206600
1206600
:~le: Gas Temperature IF)Stac~ Temperature (r)
957
257
Sect ion No.Tube Tube Fi~Pltch T'JDe Passes Tube
Rows 7hk.Configuration TransxLcng Lt.IMod trow(in)(b)(in.ht.th:(ir.xin)
(~:.)
Box
HPSH1 1. 5C 131 3xO.625x.04C 2~x4.50.1.00
HPDSI O. OC 000 0 . oxa . OOOx ,DOC ::10xO.
HPSH2 1. 5::1 131 3xO,625x.04C 25x4.50.1. 00
HPSH3 2. C 1. 131 . 3xO . 62 5x . 04 a 3, 25x4. 38 50.:, OC
Burner Box
BRNR1 ::J .000 o. OxO. OOOx . 000 OCxO.
Box
H?SH4 1. ~O C ,164 9xO.625x.053 3, 25x4. 38 55. C
: .
IInvl 1. 114 7. 3xO.500x. 040 3. 25xl;. 38 55. C l..
H?EV2 1. 50 114 3xO.500x.OI;Q 3 . 25x2 ,55.1. 00
CO/SCR
Box
HPEV3 1. 50 3xO.500x.040 25x2.5~. C 1. CO
10.HPECl ::1 1. 50 131 7. 3xO. 625x. 040 2~x4.55,::1 2. CO1:.:PSH:!.1.0 1. 50 0xO.315x.::140 25x2.55.2. CO12.HPEC2 1. ~O 114 7 .3xO. 625x, 340 25x4.5~. 0 3. CO
13.:E'Ev:114 3xO.625x,::140 3, 25x4 .55.1. CO
14.: PEV2 o. a 1. 50 114 3xO.500x,::140 25)(2.55.1.00
Box
15.IPEV3 :!.. 50 114 7. 3xO. SOCx. 040 25x2.55.1. 00
16.IPEC1 114 3xO.500x.040 25x2.55.
17.IPEC2
::'.
114 7'.3xO.500x.040 25x2.55.
18.I PEC3 l..114 3xO.500x.040 25x2.55.
44.
':'ota1 number of widths:
':'ota1 number tubes:158470ta1heating surface area:374666 (Sq ft)
TIua doc........ CODI,"", iDfo"",lioD ""', is "IIndcd for use of the indiviO.lal 01 enlity '0 wkic:h " .. oddJcs$cd and m.y conI... informal;.n lho' d pn",'ex"'. eonr.dcnl\ll . ODd
tAcmpo ~om disclos.re WIlla appt;cohle low. If the JUdcr of ,his donman is no' lbe ...aodcd rce;pinal or u.. emploY"" or 'l:cno rcspo..iblc for dc'..nnl'h. cIoc........ '0 ....
inlended Ice"",,,', you Are hereby nollt\td .n.. any dinnnina,io., dinribullOn, or eopyuq: of ,Ius eo""""'"Clno" " 1IrKlly prohir.;'ed ..,,110.. ""'lien ..,!Ionul... from VDg1.NEMI",..p""""
",,"~~*-
~eM Vogt-NEM, Incorporated - Louisville, Kentucky, USA
Do~umenl Tille:
Stttion Tille:
SKllon Rcv. DUr:
Budget quote Oocumenlluur O.le:
Vol:l-NEM Ref. So.
Sedion P.ge No,
Novemher II , 2002
209J
~-.:-
r:feM
6. TYPICAL WEIGHTS AND DIM.ENSION TABLE
(Estimated dimensions and weights - for infonnation only)
Level of prefab Weight
each fibs)nrof mode of Height Width Length
req transport (ftJ 1ft)1ft)
Module A Pressure parts harps 1.0 Rail
with headers 200,000
Module B interconnecting 300,000 1.0 Rail
Module C piping, casing, and 300 000 1.0 Rail
Module D steel attached.300,000 1.0 Rail
HP drum 1.0 Rail
500
IP drum 1.0 Truck
000
BafficslBumpers etc - Container
Inlet duct With columns 58425 Truck
attached
Burner duct With columns 36375 Truck
attached
Outlet duct Incl. Stiffeners.28000 8 Truek 8.5
Boilerstack ) 20 degree sections 55125 6 Truck
40ft long
SCR duct With columns 16310 Truck
attached
Goalpost bolted/duct BuJk
See. steel 30000 6 Container
Pumps bellows
,...
3750 1 Container
Piping & Supports 88000 8 Container
VaJves Safety+Sil.8800 I Container
Burner system 5500 2 Container
Flue gas silencer - Container
lnsul, mat's fieldconn.1150 I Container
Erect ,tools 33000 I Bulk
E&I 2200 1 Container
This do"""... eD"O'" ..!onno,iD. """ is in,...o.d for us. or the: NO,,",uol or ""y 10 wluch ;, is .doh.....! and may "'01'" 1010"""".. lhoc os privilr;od. confidential, and
oump &om disdc..... applicab3e low. If Ih, rudor of this do"""em is .011110 inlended ...ipcl or 1110 cmployoo 0' '1100' ...ponsibl. rD' dtDvcrin,: Ih, do......". 10 .110
inltodcd rcc;piall, )'0\' or. hereby notified WI ..,y chssanination. diouibu;on. 0' tOp)'UIE of this ,01M1Utlltalion is ..rialy plolubilcd ";Ihoul """00 ..\hDNo'io. tom VD".:-ont
Inco'J'O"'cd.
~~~*-
NeM
...
... Vogt-NEM, Incorporated - Louisville, Kentucky, USA
Documml Title:
Section TIlle:
Sectlo n Rev. DaCe:
Budget quole Docum~nt luue DaC~:
Vogt-SEM Rtf. No,
Seclion raKe So.
November II . 2002
2093
....'... ."' !
, z
1- -
a:I
- u_o.j
, 4;
- CI
I~
---
-4 J: -to!
tIJ
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STEAM TURBINE QUOTES
A LSTQ)M
Power
Industrial Turbines
November 7,2002
Mro Chris Ro Rogers, Po
Vice President
Sega, Inco
16041 Foster
Stilwell, KS 66085-1000
Reference:Idaho Power Company
Evander Andrews Complex
CC Conversion Study
Mountain Home, Idaho
Sega Proiect Noo 02-9999-
Our Y02129
Dear Mr. Rogers:
We have reviewed the revised operating conditions contained in your October
31 request and provide the attached performance heat balances for your useeIn addition to the performance information, we attach an outline drawing;
unfortunately, it is with the typical installation utilizing a surface condenseroThe unit does have our standard axial exhaust, as also supplied with an air-cooled condenser, but requiring a duct-transition piece to be includedo
From the commercial viewpoint, this steam turbine and 9208 MVA TEWAC
generator (0085 PF, 1308 kV) has a current estimated price of approximately
700,0000 Price is FOB proiect site, with estimated delivery of 1405 to 15months (transport consumes approximately 8 weeks). Duties are included, butno sales or use taxes of any kind are includedo The budgetary price includesour standard scope including turbine-generator safety and control system,control system cubicles, control and lubrication oil systems, gland steam systemand transition piece for the air condenser ducto
ALSTOM Power Inc.
10730 Telge Road
Houston, TX 77095-5002
Tel: [phone]
Fax: [phone]
ca rl.stendebach(!Ypower.a Istom .com
Mountain Home
BudgetEst 110702.doc
ALSTQ'M
Powe r
Page 2
Mountain Home
11/0702
Should any additional information be required, please contact us.
Very Truly Yours,
ALSTOM Power Inc.
Industrial Turbines
~,,4.
Carl A. Stendebach
Business Development Manager
Copies to:Jim Hittle-Hittle Power Technologies
Brad Thompson-Brad Thompson Co.
Regina Richardson-ALSTOM Power Inc.
Soren Olsson-ALSTOM Power Sweden
ALSTOM Power Inc.
10730 Telge Road
Houston, TX 77905-5002
Tel: [phone]
Fax: [phone]
ca rl.stende ba ch(g)powe r.a Istom .com
Mountain Home BudgetEst 11 0702.doc
LSTO'M
PRELIMINARY DIMENSION AND WEIGHT INFORMATION
FOR AN ST5 STEAM TURBINE GENERA TOR
Project:Y02129
Mountain Home
Nevada
11/07/02
Prepared by:
Date:
MODULE COMBINATION:
ST5-turbine
Exhaust direction
Generator
Lube oil unit size
CORRESPONDING LAYOUT DRAWING
ST5-C380
Axial inline
1506 gallons
CSD90020257
WEIGHTS:
Turbine
Generator
Lube oil unit (empty excl. cooler)
Lube oil unit (Operating incl. cooler)
204536 lbs
216274lbs
14330 lbs
28219 lbs
SERVICE AND MAINTENANCE WEIGHTS:
Generator rotor
Turbine rotor
Turbine upper half
35715 lbs
39494 lbs
68196 lbs
TOLERANCES:
+- 1 foot for dimensions less than 30 feet
+- 2 feet for dimensions larger than 30 feet
+- 10 % for weights
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FW: SegaJIdaho Power Page 1 of 2
Nathan Ninemire
"""""""""""""""""""""""""""""""""""""""""""""............ ..................................
From: Whinery, Rick A (HOU) (Rick Whinery(Qi Dresser-Rand.com)
Sent: Monday, November 11 , 2002 9:42 AM
To: nninemire(Qisegainc,com
Subject: FW: Sega/ldaho Power
......... ....-.......... ........................................... ............................ .......... ............................... .......... ............... .................................. ............................... .......... ""-""""'.....""" ....
Nate
Pat Harpenau asked me to forward this information to you. Sorry it is late.
Regards
Rick Whinery
-----
Original Message-----
From: Alsworth, Ronald G (WLS)
Sent: Wednesday, November 06, 2002 12:52 PM
To: Whinery, Rick A (HOU)
Subject: Sega/ldaho Power
Rick
Following is estimated performance for listed conditions:
Case 1Steam 833.3 PSIA - 945 F - 2.82 PSIAFlow 593,300 Lbs/Hr
Induction Press, 290.5 PSIA
Induction Flow 17 830 Lbs/Hr
Est. KW 73 530
Case 2Steam 832.4 PSIA - 946 F - 4,204 PSIAFlow 592 300 Lbs/Hr
Induction Press, 290.6 PSIA
Induction Flow 18,820 Lbs/Hr
Est. KW 70 005
Case 3Steam 611.3 PSIA - 947 F - 1.306 PSIAFlow 272 800 Lbs/HrInduction Press. 147.4 PSIA
Induction Flow 35,430 Lbs/Hr
Est. KW 36,696
Case 4
Steam 809,6 PSIA - 944 F - 2,82 PSIA
12/612002
FW: SegaJIdaho Power
Flow 586,000 Lbs/Hr
Induction Press, 290.5 PSIA
Induction Flow 17 830 Lbs/HrEst. KW 72 270
Page 2 of 2
Case 5Steam 808.8 PSIA - 932 F - 4.204 PSIAFlow 585,000 Lbs/Hr
Induction Press, 290.8 PSIA
Induction Flow 18,820 Lbs/HrEst. KW 68,875
Case 6Steam 377.4 PSIA - 932 F - 1.305 PSIAFlow 267 000 Lbs/Hr
Induction Press. 147.4 PSIA
Induction Flow 35,430 Lbs/HrEst. KW 33 645
Inlet Size 16"
Induction Size
Exhaust size 11 0" (Axial)
Est. Price 500 000.
Delivery 13 Months
Est. Dimensions
Length 50 Ft.
Width 18Ft.
Height 13 Ft.
Est Weights
Turbine 225 000 Lbs.
Generator 220 000 Lbs
Accessories 50,000 Lbs.
12/6/2002
Nathan Ninemire
From:
Sent:
To:
Subject:
john .schroeder~ ps.ge.com
Wednesday, November 06,20025:17 PM
nninemire ~ segainc,com
Steam Turbine Budget Pricing - Idaho Power Study
Sega 80 Deg F
Fired,pdf
Sega 80 Deg F
Unfired,pdf
Sega 95 Deg F
Fired,pdf
EP Direct Drive
Estimate,pdf
Dear Mr. Ninemire
Attached please find estimate and associated HB diagrams for the
referenced application. The performance is consistent, but the unit is
opera te at a high backpressure resul ting from the air-cooled condenser.
had to use a GE 20H last stage bucket to handle the 8.6 in HgA exhaust
pressure at the 95 Deg F fired condition.
Also, we have assumed a STAG (floating pressure) head design that
allows throttle pressure to fluctuate in response to inlet flow.
Essentially the ST acts as a simple orifice allowing the steam throttle
pressure to drop to an equilibrium point dependent upon how much flow thereis. For the reduced flow specified in the 95 Deg F unfired case, the
equilibrium point is 380 PSIG, which is far below the 611,3 PSIA anticipated
on Sega' s HB diagram. We should discuss the merits of a floating versus a
fixed pressure as it relates to operating scenarios anticipated.
Regards
John
~~Sega 80 Deg F Fired.pdf~~ ~~Sega 80 Deg F Unfired.pdf~~
~~Sega 95 Deg F Fired.pdf~~ ~~EP Direct Drive Estimate.pdf~~
John H. Schroeder Jr.
GE Power System Account ManagerPh: [phone]Fx: [phone]
GE Power Systems
STEAM
TURBINE-GENERA TOR
BUDGETARY ESTIMA
CUSTOMER:Sega, Incorporated
PROJECT:Idaho Power Study
TRACKING 1102-234
OPTION:
REVISION:
DATE:05 November 2002
GE ENERGY PRODUCTS
EV ALUA TlON, ANAL YSIS PRICING
RIVER ROAD
BLDG. 37-
SCHENECTADY, NY 12345
GE PROPRIETARY INFORMATION
GE Power Systems
Equipment Description
Turbine One (1) 76 127 kW rated , 3 600 RPM, straight condensing,
impulse type, direct drive steam turbine-generator designed for
normal inlet throttle steam conditions of 833 psia, 945 o f , with
uncontrolled admission at 290 psia, exhausting to 2.82 psia.
Generator One (1) 89 561 KVA rated , 3 600 rpm , 2 pole, 3-phase , 60 Hz
800 volts
, .
85 pf, totally enclosed water-to-air cooled (TEWAC),
synchronous generator.
Exciter One (1) brush less excitation system.
Controls One (1) GE Mark VI digital steam turbine control system.
Budgetary Proposal for Steam Turbine-Generator
Page
GE PROPRIETARY INFORMATION
GE Power Systems
Estimated Ship Date 14 Months from P.O. Date
Delivery is subject to prior sales. Actual delivery date will be
established based on factory loading and equipment selected.
Estimated Price $ 9,000 000 USD
Prices are for estimating purposes and do not constitute an offer of
sale. This price is Ex-Works and excludes delivery, taxes, and
duty and is based on GE Power Systems standard terms and
conditions of sales.
Estimated Performance See attached heat balance diagrams
Operatinq Case Inlet Flow Admission Flow Exhaust flow KW Output
80 o , Fired 593.3 kpph 17,8 kpph 608.9 kpph 127
95 o , Fired 592.3 kpph 18.8 kpph 608.9 kpph 739
80 o , Unfired 272.8 kpph 35.4 kpph 307.1 kpph 193
Budgetary Proposal for Steam Turbine-Generator
Page
GE PROPRIETARY INFORMATION
GE Power Systems
Turbine
Base mounted on structural steel baseplate with optical al ignment
pads for easy leveling
Maximum factory packaging including lube and control oil piping,
instrument tubing and steam seal piping, with instrumentation and
controls wired out to junction boxes
High pressure casing
Cast alloy steel construction
Horizontally split with precision machined joints
Freely expanding centerline support to tolerate cyclic thermal
ramps
Access ports for borescope inspection and field balancing
Exhaust casing
Exhaust orientation: Axial
Fabricated steel exhaust casing
Cascaded moisture drains for extracted steam path moisture
Conical sidewall diaphragms for improved steam guidance
Upper half casing mounted blowout diaphragm provides protection
against abnormally high exhaust pressures
Bearing bracket designed for high support stiffness
Access panels permit last stage inspection and field balance
correction
Rotor
Budgetary Proposal for Steam Turbine-Generator
Page
GE PROPRIETARY INFORMATION
GE Power Systems
Solid rotor forging has integral wheels, thrust collar and coupling
for maximum long term reliabil ity
Mechanically attached aerodynamic impulse type buckets
Peened attachment of shroud bands to bucket tips
Designed for thermal cyclic operation
Nozzles and diaphragms
Welded steel construction
Nozzle blades and covers made of 12 Cr material
Nozzle metal sections of high aerodynamic performance pitched to
avoid serious nozzle passing frequency excitation of rotor blades
Moisture removal devices in high moisture areas
Centerline supported to maintain precise sealing clearances
Labyrinth style, spring backed segmented interstage and gland
packing made of metallic material
Journal bearings
Self aligning tilting pad high and low pressure journal
bearings
Cast babbitt on steel construction
Thrust bearings
Self equalizing/aligning tilting pad type thrust bearings
Cast babbitt on steel construction
Dual thrust bearing shims to fix axial position and establish thrust
bearing clearance
Budgetary Proposal for Steam Turbine-Generator
Page
GE PROPRIETARY INFORMATION
GE Power Systems
Inlet stop and control valve
Combined stop and control valve for use in sliding pressure control
application
Valve to be mounted by the customer in main steam line
Integral coarse mesh steam strainer
Fine mesh start up strainer
Spring support
Limit switches for position indication
Valve exercising capability
Auto start kit
Three casing metal thermocouples
One differential expansion probe
Monitoring done by Mark V turbine control system
Admission Valve Gear
One butterfly type admission stop valve for each uncontrolled
admission
One butterfly type admission control valve for each uncontrolled
admission
One in-line admission steam strainer for each uncontrolled
admission
Shipped loose to be mounted in customer steam piping
Steam Seal System
Pneumatically operated automatic steam seal regulating valves
mounted on turbine skid
Budgetary Proposal for Steam Turbine-Generator
GE PROPRIETARY INFORMATION
Page
GE Power Systems
Separately skid mounted gland condenser system with AC motor
driven exhauster
Interconnecting piping by customer
Exhaust hood spray system
Stainless steel spray nozzles and piping
Temperature sensor and control valve mounted externally for ease
of maintenance
In line strainer to eliminate plugging of the spray nozzles
Turning Gear
. AC motor driven
Clash type design
Local manual engagement
Oil pressure switch interlock prohibits operation with low oil
pressure
Auto disengage
Hand crank for manual operation
Thermal insulation
, .
Removable thermal blanket type insulation
Material: Fiberglass over fiberglass with stainless steel mesh and
hooks
Shipped loose for installation at site
Turbine factory tests
Internal clearance check
Budgetary Proposal for Steam Turbine-Generator
GE PROPRIETARY INFORMATION
Page
GE Power Systems
Generator
Contact check of horizontal joint, vertical joint and valve chest
cover( s)
Hydrotest of stop valve and high pressure casing
High speed turbine rotor balance and overspeed run up to 112%
rated speed
General
Totally enclosed water to air cooled (TEWAC)
Base mounted and packaged for ease of installation
Equipment meets or exceeds the following codes and standards:
IEEE, CE Stamp, NEMA, NEC, IEC and ANSI
Indoor installation
Shaft grounding brush rigging with dual carbon brushes
Tilting pad journal bearings
Insulated collector end bearing with off line test capability
Generator Field
Integral Cr-Mo-, boreless, rotor forging
Class F insulation with Class B temperature rise
18Cr-18Mn non-magnetic stainless steel retaining rings
Non-magnetic wedges
Radial flow direct cooled field
Finger type amortisseurs
Budgetary Proposal for Steam Turbine-Generator
GE PROPRIETARY INFORMATION
Page
GE Power Systems
Standard factory tests
Resistance test
. AC high pot test
Polarization index
Overspeed test
Balance guarantee, oe::: 1.5 mils p-
Shorted turn test
Generator Stator
Stator windings have Class F Micapal HT insulation with Class B
temperature rise
Stator windings have single shot braze series loop connection
Provision for permanently mounted flux probe
Generator stator heaters
Standard factory tests
Resistance test
. AC High Pot, 2E+1 K test
Pre-assembly armature bar hi pot test
Polarization index
RTD functional test
Wiring and instrumentation
All wiring meets UL and FM approval
Voltage separated junction boxes
Consolidated instrumentation and wiring connections
Budgetary Proposal for Steam Turbine-Generator
Page
GE PROPRIETARY INFORMATION
GE Power Systems
Stator slot RTD's in each phase
Hot and cold gas temperature sensors
. Two dual element temperature sensors per bearing
Liquid level detector, SPST, single setting
. Two Bently Nevada 3300 Series vibration probes per bearing
Coolers
. Two duplex roof mounted two pass horizontal air coolers
Meet TEMA Class C standards
Cooler tube material- 90/10 CuNi
Cooler tube fins- aluminum
Carbon steel tube sheet material, water boxes and flanges
Exciter
Brushless Excitation System
Rotating diode wheel used to rectify rotor output with redundant
diodes
Rotor and stator have resin impregnated Class F insulation with
Class B temperature rise
. EX2000BR digital excitation controls
Fully integrated with Mark V steam turbine controls
10S functions done in Mark V
Automatic (AC) voltage regulator with R/L control (IOS)
Manual (DC) voltage regulator with RIL control (IOS)
Budgetary Proposal for Steam Turbine-Generator
Page
GE PROPRIETARY INFORMATION
GE Power Systems
Transfer voltmeter (IDS)
Voltage regulator transfer (IDS)
On/Off control (IOS)
Exciter field amps and volts (IDS)
Under (UEL) and over (DEL) excitation limiter
Automatic and manual reference follower
Generator field thermal protection
Impedance compensation
Generator field ground detection
Volts/hertz limiter
NEMA 1 Construction
Reactive Current Compensation (RCC)
Bi directional tracking
. PT failure alarm (voltage balance)
Lube and Control Oil System
Lube and control oil system use common remotely mounted reservoir
divided into two separate sections
. Fyrquel , fire resistant fluid , is used as the control oil
Welded carbon steel lube and control oil reservoir with internal
phenolic coating
. Two full size AC motor driven lube oil pumps
. Two full size AC motor driven control oil pumps
. One 120VDC motor driven emergency lube oil pump and a DC motor
Budgetary Proposal for Steam Turbine-Generator
Page
GE PROPRIETARY INFORMATION
GE Power Systems
starter shipped loose to be mounted locally by customer.
. Two full capacity lube oil coolers
One AC motor driven lube oil reservoir vapor extractor
. Two full capacity lube oil filters in a duplex arrangement
. Two full capacity control oil filters
. Two redundant control oil accumulators
. One control oil conditioning system
. 2 out of 3 voting trip solenoid arrangement
Stainless steel lube and control oil supply piping
Interconnecting piping by customer
Lube and control oil supplied by customer
Oil pumps and motors are assembled and tested for pressure , flow
vibration and power input
Complete oil system is test run at the factory
Turbine Controls and Instrumentation
. GE Mark VI Simplex Steam Turbine Control System
Single channel digital control system with independent backup
emergency overspeed protection module
Mark VI Cabinet (36"W x 90"H x 20"0), NEMA 1 enclosure
Operator interface (Industrial Grade PC)
Control functions
Speed/ Load control
Inlet pressure control
Automatic extraction/admission control
. Turbine-generator protectives
. On & off line testing of protectives
Budgetary Proposal for Steam Turbine-Generator
Page
GE PROPRIETARY INFORMATION
GE Power Systems
Monitoring of discrete and analog signals
. RS-232 or Ethernet communications link with Modbus protocol for
monitoring and control from a Distributive Control System (DCS)
Interconnecting wiring by customer
Turbine Instrumentation (Monitoring done by Mark VI)
Bently Nevada 3300 series radial vibration probes , 2 per bearing.
Bently Nevada 3300 series axial position probe.
Bently Nevada 3300 series Keyphasor.
. RTD's/thermocouples for temperature monitoring
Pressure and temperature indicator switches for alarm and tripping
Temperature sensors located in all turbine bearings per API 670 to
monitor bearing metal temperature
Local Monitoring Panel
Five digital electric pressure gauges
Turbine trip and reset controls
Digital tachometer
Warranty
Standard warranty is one year from date of first synchronization or two
years from ex works delivery, whichever occurs first.
Miscellaneous
Standard factory testing of equipment.
. 6 month preservation for shipping/indoor storage for both turbine and
generator
SpeCial turbine/generator tools
Budgetary Proposal for Steam Turbine-Generator
Page
GE PROPRIETARY INFORMATION
GE Power Systems
Eye bolts
Guide pins for casing removal
Balance weights and tools
Electric bolt heaters if necessary
Tools for generator field removal
Instruction books, 10 Copies
Items Not Included In This Estimate
Technical direction of installation
Turbine-generator training course
. Turbine, generator or control system spare parts
Performance Testing
Transportation
Duties and taxes
Budgetary Proposal for Steam Turbine-Generator
GE PROPRIETARY INFORMATION
Page
GE provided preliminary drawings with their budget
estimate. These drawings are not included in this
appendix because they contain information that
considers confidential and proprietary.
SIEMENS
Westinghouse
Sega for Idaho Power
Evander Andrews Comples
Budget 75 MW Admis-Cond
December 3, 2002
SCOPE OF SUPPL Y
Indoor Installation
Turbine Description
Single Casing design Admission Condensing
Direct Drive Turbine Speed 3600 rpm
Base Frame Mounted with Machined Surface, including Leveling Plate and Vertical
Jacking Screws. (Anchor Bolts Provided by Customer)
. Multi-valve, Multistage
Hydraulically Operated Emergency (Main) Steam Stop Valve
Integrated (Permanent) Steam Strainer, Removable without Disconnecting the Inlet
Steam Piping
Outer casing and Guide Blade Carriers Horizontally Split
Downward/Upward Exhaust
Admission Nozzles
Inlet Nozzles Upward or Downward
. 2 lobe journal and thrust bearings
Jacking Oil Connections for Turbine and Generator Bearings
Carbon Steel Drain Piping up to Turbine Baseframe
Manual Drain Valves
Turbine Internal Steam Piping Carbon Steel per DIN , all Interface Flanges per ANSI
Control Oil piping Stainless Steel and Lube Oil Supply and Return Piping Carbon
Steel, all Interface Flanges terminated at Base Frame per ANSI
Control Oil Bladder Accumulator
Junction Boxes
Local Gauge/Transmitter Rack
Probes/Proximeters Extension Cables for Bearing Vibration , Axial Displacement and
Key Phasor
SIEMENS
Westinghouse
Sega for Idaho Power
Evander Andrews Com pies
Budget 75 MW Admis-Cond
December 3, 2002
Bearing RTD's (2-PT100 Dual Element per Journal Bearing and Thrust Bearing Side)
Turbine Control System consisting of Digital Governor Siemens PCS - 7, I/O
Interface to a DCS via MODBUS, Speed Control, Admission / Inlet pressure Control
Turbine Protective devices; dual Solenoid Valves for Remote Trip (de-energize to
trip), 2 out of 3 working Electronic Overspeed Trip, Low Lube/Control Oil Pressure
Trip, High Shaft Vibration/Shaft Displacement Trip, 3300 Bentley Nevada Vibration
Monitoring
Magnetic Speed Pick-Ups (3)
. Connection Points for Purchased Supplied Instruments for ASME PTC-6 Test
Lube/Control Oil System (Separate Skid); including Carbon Steel Oil Reservoir, AC
Motor Driven Main Oil Pump, AC Motor Driven (100%) Auxiliary Oil Pump, DC Motor
Driven Emergency/Run Down Oil Pump including DC Contactor, AC Motor Driven
Jacking Oil Pump, Dual Oil Filters with Changeover Device for Lube and Control Oil
(one each), 2x100% Oil Cooler with Changeover Device, Supply Oil Piping Carbon
Steel , Return piping Carbon Steel , Control Oil Piping Stainless Steel , CuNi Tubes for
Lube Oil Coolers
Testing and Inspections per Siemens standard program
Balance and Overspeed Test at Operating Speed
Standard Paint Finish
Seaworthy Packing
SIEMENS
Westinghouse
Sega for Idaho Power
Evander Andrews Comples
Budget 75 MW Admis-Cond
December 3, 2002
Synchronous Generator; Two Pole, 3600 RPM, 60 Hz, 86 MVA, TEWAC, 0.85PF
13.80kV, Base Frame Mounted , Brushless Excitation with Rotating Rectifier and
Permanent Magnet Generator, TEWAC Construction, Maximum Inlet Water 85O
Dual Coolers, CuNi Cooler Tubes; Carbon/Stainless Steel Tube Sheets; Carbon
Steel Headers
Automatic Voltage Regulator and associated electricals
High Voltage terminal box with CT's, PT's and LA
Neutral grounding resistor
Limits of Supply
Terminal Points at Turbine, Steam Side:
Live Steam Emergency Stop Valve Inlet Flange
Admission Steam Flanges Located at Casing Bottom Side
Seal Steam Inlet Flange at Baseframe Edge
Free Issue Items:
Emergency Stop Valves for
Extraction/AdmissIon Steam Lines Flanged Connections at the Valves
Cooling Water:
Lube Oil Cooler Inlet and Outlet Flanges at Coolers
Generator CoolinQ Elements Inlet and Outlet Flanges at Coolers
Generator Leads:Terminal Boxes , Located AlonQside Generator
Motors:Terminal Boxes at Motors
Control & MonitorinQ Panels:Terminal Blocks in the Panels
Terminal Boxes:Cable Glands of OutQoinQ Cables by Customer
Exclusions:
Balance of Plant equipment and items not specifically mentioned (generator core monitor
system stabilizer, geno protection , synchronizing gear); as well as taxes , customs, duties, other
interests, operating and lubrication medium, installation and commissioning are not included.
SIEMENS
Westi nghouse
Sega for Idaho Power
Evander Andrews Comples
Budget 75 MW Admis-Cond
December 3, 2002
Technical Data:
OPERATING POINT Case
833
945
593 300
290
484
830
Downstream flow Ib/hr 611 130
611 130
100
(1) Admission pressure at the turbine flange. Stop valve and strainer supplied loose for
installation in customers pipework.
(2) Output at generator terminals, includes all electrical and mechanical losses, incl. parasitic load
for main lube oil pump.
Output at generator terminals estimated with +/- one percent tolerance.
SIEMENS
Westinghouse
Sega for Idaho Power
Evander Andrews Comples
Budget 75 MW Admis-Cond
December 3, 2002
Delivery Period:
Delivery period ex-works presently is 13 months.
Price:
Budget price for one turbine generator set defined above, delivered FOB German Seaport
according to INCOTERMS 2000 including seaworthy packing. Freight, duties, installation and
commissioning excluded.
us $ 5,900 000.
Conditions:
The delivery period begins after receipt of technically and commercially clarified order. The
prices offered are budgetary and based on present costs; in case of firm quotation, subject to
confirmation. The quoted prices are based on Siemens Westinghouse Power Corporation
standard terms and conditions and progressive payments (Selling Policy 1270).
We hope that this budgetary information is sufficient for your immediate needs, should you need
additional information or have questions; please contact us.