Application of Solar Technology to Today's

Energy Needs—Vol. II

September 1978

NTIS order #PB-289762
Library of Congress Catalog Card Number 78-600060

For sale by the Superintendent of Documents, U.S. Government Printing Office

Washington, D.C. 20402, Stock No. 052-003-00608-1

ii
PREFACE

The previous volume of this report presented the results of an

analysis of a large number of solar energy systems designed to meet

the energy requirements of homes, apartment buildings, shopping

centers, industries, and small communities. This volume provides

detailed information about the assumptions made in these calculations and the techniques employed.

An attempt was made to present a broad sampling of the systems which may be available during the next 10 to 15 years. The

richness and variety of opportunities is astonishing; chapter IV

describes several hundred different systems designs on separate

charts. It is difficult to thumb through these pages without admiring

the ingenuity and inventiveness of the industry. The richness of this

base of ideas and the encouraging rate at which new ideas are

emerging, are one of the greatest assets of solar technology.

Apart from presenting a catalog of system concepts, this

volume describes a methodology for evaluating the economic and

technical merits of small-scale energy systems which can be owned

by any of a variety of owners. We hope that the techniques described here will be widely applicable to analysis of small-scale

energy systems. The first chapter presents a method for computing

the effective cost of energy as a function of the financial expectations and tax status of several different kinds of owners. The second

presents a method for computing the performance of different

kinds of systems operated in an optimum way. A third chapter

presents a technique for parametrizing uncertainties about future

fuel and electricity prices. The final pages contain a Iist of corrections for errors discovered in volume 1.

If the bulk of the resuIting work is intimidating, we can only say

that we could find no way to abbreviate the presentation without

sacrificing a sense of the richness of the alternatives Or the complexity of the problem of choosing between them.

.

i i i
OTA Solar Energy

Project Staff

Lionel S. Johns, Energy Program Manager

Henry Kelly, Project Leader

David Claridge John Furber John Bell

OTA Energy Staff

Richard Rowberg

Lynda Brothers

Marvin Ott

Dorothy Richroath

Linda Parker

Lisa Jacobson

Joanne Seder

Radmilla L. Bartok

Rosaleen Sutton

Technical Assistance

Oak Ridge National Laboratories

Sandia Laboratories

Lawrence Livermore Laboratory

Department of Energy

Division of Solar Energy

Contractors

American Institute of Architects

Research Corporation

Environmental Law Institute

Thermo Electron Corporation

OTA

Publishing

Staff

Consultants

Timothy Adams

Linda Ashworth

Richard Bourbon

Allen Brailey

Jack Burby

Peter Ceperley

Thomas Erwin

George Harrison

Grayson Heffner

Sam Iker

Ann Cline Kelly

Renal Larson

Robert Morse

Corbyn Rooks

Edward Sproles

Donald Veraska

Don Watt

Mary Zalar

Cotton & Wareham

Jet Propulsion Laboratory

university of Oklahoma, Science&

Public Policy Program

John C. Holmes, Publishing Officer

Kathie S. Boss Joanne Heming

v
OTA Solar

Advisory Panel

Jerry Grey, Chairman

Private Consultant

William W. Caudill

Caudill, Rowlett & Scott

John J. Gunther

United Conference of Mayors

Klaus P. Heiss

ECON, Inc.

Morton Hoppenfeld

University of New Mexico

Charles Luttman

The Ralph M. Parsons Company

James MacKenzie

Massachusetts Audubon Society

Paul Maycock

Texas Instruments’

Marjorie Meinel

University of Arizona

Larry T. Papay

Southern California Edison Co.

Paul Rappaport

RCA-David Sarnoff Research Center**

Floyd E. Smith

International Association of

Machinists

Ephraim M. Sparrow

University of Minnesota

OTA Energy

Advisory

Committee

Milton Katz, Chairman

Director, International Legal Studies, Harvard Law School

Thomas C. Ayers

President and Chairman of the Board

Commonwealth Edison Company

Kenneth E. Boulding

Professor of Economics

Institute of Behavioral Science

University of Colorado

Eugene G. Fubini

Fubini Consultants, Ltd

Levi (J. M.) Leathers

Executive Vice President

Dow Chemical USA

Wassily Leontief

Department of Economics

New York University

George E. Mueller

President and Chairman of the Board

System Development Corporation

Gerard Piel

Publisher, Scientific American

John F. Redmond, Retired

Shell Oil Company

John C. Sawhill

President

New York University

Chauncey Starr

EIectric Power Research

Institute

*Resigned after accepting position with U.S Department of Energy.

* * Resigned after accepting position as Director of the Solar Energy Research Institute

v;
Contents

Chapter

1. Analytical Methods . . . . . . . . . . . . . . . . . . . . . . . . . . .

I 1. Current and Projected Fuel Costs .

Ill. Calculation of Backup Requirements

. . . . . . . . . . . . . . . . . . . . . . . . . . .

..,..........,.. . . . . . . . . . .

Iv, Results of Systems Analysis. . . . . . . . . . . . . . . . . , . . .

v. Assumptions Made in the System Analysis . . . . . . . . . , . . . . . . . .

VI. A Detailed Analysis of the Impact of On site Equipment on UtiIity

costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Errata for Volume I . . . . . . . . . . . . . . . . . .

Page

3

27

43

95

667

729

753

NOT E: This Volume discusses the analytical methods used and provides detaiIs on each

system analyzed. Volume I summarizes the analysis of system performance and costs,

discusses policy, major impacts and constraints on solar markets, and reviews direct solar

technology,

vii

Chapter l.–ANALYTICAL METHODS

Page

Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3

Social Discount Theory. . . . . . . . . . . . . . . . . . . 4

Private Evaluation of Costs . . . . . . . . . . . . . . . 5

Quantitative Evaluation of Financing

Alternatives . . . . . . . . . . . . . . . . . . . . . . . . . . 5

Some Basic Equations . . . . . . . . . . . . . . . . . . . 8

Baseline Assumptions . . . . . . . . . . . . . . .......18

Inflation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18

Homeowner Financing . . . . . . . . . . . . .......18

Rental Properties. . . . . . . . . . . . . . . . . .......19

Industries . . . . . . . . . . . . . . . . . . . . . . . .......21

Utilities . . . . . . . . . . . . . . . . . . . . . . . . . .......21

LIST OF TABLES

Table No. Page

l. Baseline Assumptions Used to Prepare

Figures l-1 and l-2 . . . . . . . . . . . . . . . . . . . . . . . 7

Table No. Page

2. Symbols Used in Financial Analysis . . . . . . . . 9

3. Summary of the Financing of PublicOwned Utilities in the United States 1973-74.23

4. Historic Pattern of lnflation and Rates

of Return on Utility Equity . . . . . . . . . .......24

LIST OF FIGURES

Figure No. Page

l. Sensitivity of Capital Charges to

Consumer’s Discount Rate . . . . . . . . . . . . . . . 6

2. Sensitivity of Capital Charges to Rate of

Return for Corporate Owner. . . . . . . . . . . . . . . 7

3. Cumulative Distribution of Chemical,

Petroleum Refining, and Paper and Pulp

Companies Willing To Invest in

lnplant Cogeneration Equipment Versus

internal Rate of Return on Investment .. ....22
Chapter I

Analytical Methods

INTRODUCTION

Chapters in volume I have established the technical feasibility of

numerous techniques for converting sunlight into other useful forms of

energy. The present discussion describes a variety of methods for measuring

the value of these systems. It is important to recognize that many of the

critical variables cannot be characterized with great precision and cannot be

expressed in terms which permit easy comparison. Costs and benefits apply

to different groups of investors and consumers (requiring a comparison between costs extracted from one group and benefits enjoyed by another), occur at different times, and occur in different areas (requiring a comparison

between impacts on the profitability of individual firms, the environment,

employment, national security, civil liberties, etc.). Such issues exceed the

capabilities of conventional economic theory. The choice between alternative

energy strategies must therefore ultimately reflect a political judgment and

must be made without the comfort and guidance of mathematically precise

forecasts. It would be dishonest to obscure the fact that such political

judgments are necessary, and it is essential to be modest about the capabilities of analysis. All that is possible is to develop techniques for systematically evaluating aspects of the alternatives which can be quantified.

The perceived costs of solar energy depend strongly both on the

perspective from which they are examined and on the methods used for

evaluating them. It is fair to assume that investors are attracted to solar

equipment only if they are able to earn rates of return comparable to those

earned in other types of investments exhibiting Similar risks. The measure of

merit, which is the primary basis for economic comparisons in this report, is

the price paid by the ultimate consumer of energy. This price depends on the

kind of equiptment used and on the economic expectations of the owner of

the equipment. The following discussion develops a self-consistent technique for reducing the large number of variables which affect this price to an

easily interpretable average consumer energy price.

The financial merit of investments can be assessed in a number of different ways. Methods vary in their sophistication, and alternative investments

are often ranked differently depending on the method used. The techniques

include a comparison of:

— initial capital investment;

—the “payback time, ” or the time required for cumulative income to

equal the initial investment;

—rates of return from the investment; and

—the “present value” of investments.
4 ● Solar Technology to Today’s Energy Needs

The techniques actually used to compare investments vary greatly and frequently involve a number of factors which are not

easy to quantify. Critical decisions depend

on the financial condition of the investor,

his perception of the risk involved, the skill

with which the proposed equipment is marketed, the availability of funding, his attitude toward diversifying his investment

portfolio, and other psychological factors.

The simple comparison of initial costs, for

example, will almost certainly continue to

be one of the most critical variables in making decisions, in spite of the fact that sophisticated analysis might show that decisions

based on this comparison may be unwise. It

is important, therefore, not to be mesmerized by quantitative measures of merit when

attempting to assess the marketability of

equipment.

The bulk of the analysis in this report is

based on discounted cash-flow (or “present

value”) analysis — a systematic way of evaluating the profitability of different kinds of

investments.

SOCIAL DISCOUNT THEORY

Before proceeding into the detaile d

analysis of private investment decisions, a

brief review will be given of an entirely different technique for evaluating the cost of

energy equipment. The “social” cost of

energy —or the cost perceived by society as

a whole— may differ greatly from the costs

perceived by individual producers or consumers, even if the full costs of environmental damage and other immediate social disbenefits are identified and charged to the

appropriate equipment owner. For example,

today’s market does not accurately reflect

the cost of resources which are being depleted but are not now in short supply. This

lack of foresight is encouraged by policies

designed to keep prices artificially low (price

regulations, concessionary tax policies,

etc.). Another reason for the differences between private and social costs is the way in

which any analyses made by private investors discount future costs and benefits with

respect to present costs. The interest rate,

which should be used to evaluate the real

marginal productivity of capital from the

point of view of society as a whole (the socalled “social discount rate”), is the subject

of considerable dispute.

The value of societal costs computed in

this way must be treated with great caution.

If ranking energy alternatives with these

simple discounting procedures results in

very different priorities than the ranking

which results from conventional financial

analysis, however, it will be important to be

able to understand whether the difference

really implies that conventional financial

decisions are resulting in a sacrifice of social

benefits for short-term private gains. In this

sense calculating a “societal cost” can serve

as a kind of warning mechanism, but much

work remains to be done after the warning

has been received. It must be noted that this

technique does not eliminate the difficulty

of assigning a just value to goods or services, since all prices used in the calculation

are estimates of prices in the open market;

determining a real marginal cost to society

for each item costed would give a better

answer but there is no agreement about how

to conduct such estimates.

It might be thought that the Federal Government would make decisions to maximize

social benefits, but the argument of how to

measure the real value of a Federal investment is more complex than the debate over

techniques used to measure “social value. ”

It could be argued, for example, that if the

Government extracts capital from society, it

must invest this capital so as to yield an effective rate of return equivalent to that

which would be earned on the money in private hands. This is, in effect, the current policy of the U.S. Government. The basis for

Federal procurement is dictated by the Office of Management and Budget, which has

declared that the Government should invest

funds in a manner which earns a rate of

return equivalent to that earned by a typical

private concern “before inflation and after

taxes.” This is declared to be 10.0 percent. ’

1OMB Circular A-94.
Ch I Analytical Methods ● 5

It is clear, however, that this rigid formula

maximizes social benefits only if it assumed

that social benefits are maximized by private investment decisions. I n several European nations different discount rates are applied to projects on the basis of political

judgments about the social merits of different technologies and the technique has

been used in the past by the United States as

an implicit subsidy to water projects, rural

electrification, and other investments felt to

be in the public’s interest.

PRIVATE EVALUATION OF COSTS

This analysis provides quantitative measures of the financial attractiveness of solar

energy measured from four separate perspectives:

1. An individual contemplating investing

in equipment for his private residence.

2. A corporation which will include the

cost of the solar energy in the price of

the company’s product or service (the

corporation might own an apartment

building, for example, and include energy costs in the rent, or it might own a

manufacturing concern using solar

energy to provide power for manufacturing processes).

3. Utility ownership (both private and

municipal utilities are examined).

4. Federal, State, or municipal governments.

The economic perspectives of these four

types of investors differ in a number of respects. Each has different expectations

about the profitability of investing in solar

equipment; has access to different types of

financing; is subject to different rates of interest by lenders; has different tax status (tax

rates and allowed deductions and credits

differ); and each compares alternatives using techniques which differ greatly in sophistication. As a result, separate analysis is necessary to predict whether investors in each

group would be attracted to solar energy.

Separate analysis is also necessary to measure the impact of proposed policies on each

type of owner since each group is infIuenced

by incentives in different ways. There are

also great differences between investors in

the same category, and the categories themselves do not reflect the full complexity of

the situation. The analysis which follows

selects representative examples from each

group.

Utilities’ perspectives on energy costs are

unique since while a utility’s customers pay

a price which represents the average cost

and make investments on this basis, the utility will compare prospective new investments on the basis of higher marginal costs;

the costs of electricity and the cost of fossil

fuels from some new sources are significantly higher than the average or “imbedded cost” of energy from all generating

sources. 2

QUANTITATIVE EVALUATION OF

FINANCING ALTERNATIVES

The cost of operating any kind of energy

equipment can be divided into four broad

categories:

1.

2.

3.

Capital Costs.–These include the cost of

paying investors for their funds, and

any taxes and insurance which must be

paid on tangible property. In most

cases, all of these costs are directly proportional to the initial cost of the system.

operating and Maintenance (O&M)

Costs. -These include costs of keeping

equipment in repair, paying operators,

etc., but do not include fuel costs.

Energy Costs.–These include the price

paid-for all fossil fuels and electricity

used by the equipment. In cases where

energy can be sold to a utility, the

owner’s energy costs are reduced by the

amount of income received from this

source.

‘Paul L. Joscow, “Inflation and Environmental Concern: Structural Change in the Process of Public Utility Price Regulation, ” 17,2 (autumn 1974), p 291,
6 ● Solar Technology to Today’s Energy Needs

4. Replacement Costs. -These include the

cost of replacing those large pieces of

equipment which wear out before the

bulk of equipment in the system.

Most of the differences between owners

are reflected in the cost of capital, since this

this represents differences in tax status. It is

shown later that the component of the average cost of energy to the final consumer,

which is traceable to capital costs, can be

written in linear form regardless of ownership. This capital cost is written in the

following form:

average capital charges perceived

by the final consumer of energy

= kl X (initial cost of equipment)

The constant in this equation (kl

), called the

“levelized fixed charge rate, ” represents the

ratio between the portion of consumer

prices attributable to capital-related costs

and the initial cost of equipment. Its value is

shown in figures l-l and I-2 for severa l

assumptions about ownership. The assumptions used to prepare these curves are shown

in table l-l (the origin of these assumptions

are discussed in a later section). The figures

implicitly assume inflation, since the interest rates and rates of return expected

reflect actual market rates.

Figure l-l shows the relationship between

capital charges and the consumer’s discount

rate. Figure I-2 shows relationship between

capital charges and the rate of return expected by a corporate owner. The capital

costs charged to consumers by the corporate owner are assumed to be constant during the lifetime of the plant (this is usually

called “normalized” accounting), and therefore the average cost of capital to the consumer is independent of the consumer’s discount rate.

Figure I-1 .—Sensitivity of Capital Charges

to Consumer’s Discount Rate

0 5% 10% 1 5 % 2 0 % 250/.

discount rate
Ch I Analytical Methods ● 7

Figure 1-2.—Sensitivity of Capital Charges

to Rate of Return for Corporate Owner

1

0.05 Baseline case

Company’s Internal required rate of return (after taxes)

(Return on common stock in utility case)

Table l-1.— Baseline Assumptions Used to Prepare Figures I.1 and I.2.

————.—.

Homeowner Homeowne r

Federal (new con- (home im- Real estate

Government struction ) provement) investo r Industry

Public

utility

—

o

.09

.53

.09

.122

.13

.348

D DB

30

.50

30

.02

.0025

.10

.055

0

D DB

Municipa l

utility

0

0

0.06

1.00

0

0

0

0

.

—

o

30

.02 ’

.0025

o

.055

0

—

.16

1.0

variable

.25

variable

o

.10

.25

.20

.70

Required rate of return

Down payment fraction

Interest on loan

or bonds . . . . . .

Debt fraction . . . . . . . .

Earnings on pfd stock

Fraction of pfd stock. .

Earnings of common

stock . . . . . . .

Fraction of common

stock . . . . . . . .

Depreciation: . . . . . . .

Depreciation period. . .

Marginal income tax

rate (combined Federal & State) . . . . . . . .

Life/term of loan (yrs). .

Property tax rate . . . .

insurance rate . . . . . . .

Investment tax credit

rate . . . . . . .

Inflation rate. ., ... . .

Salvage value ($). . . . . .

Depreciation of

replacement .

.09

.75

—

o

.12

1.0

—

o

.10

.75

—

o

.10

.30

—

“o

—

o—

o

— — — — —

o

—

o—

o

DDB

15

0

SL

30

0

— —

o

30

0

0

.35 .35

30 10

.02 .02

.0025 .0025

.50

30

.02

.0025

.50

30

.02

.0025

0

0

0

0 0

.055 .055

0 0

0

.055

0

.10

.055

0

— — — D DB S L

SL = Straight-line depreciations DDB = Double. declining balance depredation

NOTE All costs are levelized over 30 years

. Payments in lieu of taxes
8 ● Solar Technology to Today’s Energy Needs

The routine operating and maintenance

(O&M) costs of a system are written in the

following form:

average O&M costs perceived

by energy consumer

= k2 X (O&M cost in first year

of the system’s operation)

where the constant k2 depends on the consumer’s discount rate, the Iife expectancy of

the system, and on the average rate of inflation. It is assumed that operating costs do

not change in constant dollars for the life of

the system. This represents a considerable

simplification of real cases, since the costs

of maintaining and repairing real systems

vary from year to year and overall maintenance costs tend to increase as the system

ages. The approximation used here is necessary, however, since it is difficult or impossible to estimate the maintenance schedules

reliably, particularly for untested or hypothetical systems.

The fuel costs are written in the following

form:

average energy costs

perceived by consumer

= k3 X (energy costs in the first year

of the system’s operation)

where k3 depends on the life expectancy of

the system, the consumer’s discount rates,

and assumptions about the rate at which

energy from conventional sources increases

in price.

The replacement costs are somewhat

more complex, since they depend on the

number and schedule of replacements.

Using the terms defined here, the levelized annual cost of energy to the ultimate

consumer of that energy (which is called

PRICE) can be written in the following form:

PRICE = k, x (initial price of equipment)

+ k2 x (initial O&M costs)

+ k3 x (initial energy costs)

+ (Ievelized replacement costs)

The remainder of this discussion is directed

towards a detailed analysis of the value of

these constants for a variety of assumptions

about ownership, costs of capital, and regulatory policy.

SOME BASIC EQUATIONS

The present value of all consumer energy

expenses can be computed as follows:

PRESENT VALUE (d) = (1)

N

[energy-related expenses in year t]

(1 +d)t

t=o

where N is the lifetime of the system in

years. (Table I-2 contains a dictionary of

variables used in this section and can be

used for reference. ) The function PRICE was

defined previously to be the average cash

outlay which, if paid in equal amounts during the life of the system, would result in the

same present value as the actual cash flow.

This can be computed from the previous

function as follows:

PRICE (d) = CRF(d,L) X [PRESENT VALUE (d)] (2)

(3)

where CRF(d,L] is a constant called the

“capital recovery factor. ” (The name results

from the fact that CRF(d,L) is also the ratio

between the annual payments on a loan and

the initial value of the loan if it is for L years

and pays an interest rate d.) The price function is very closely related to the present

value of an investment calculated using

conventional techniques.

Federally Owned Equipment

A variety of techniques are used to evaluate Federal investments. The following

discussion will follow the procedures suggested for use in internal planning by OMB

Circular A-94. This procedure requires the

estimate of both discounted costs and benefits, but since the benefits are assumed to be

identical for all systems compared only the

procedure for evaluating costs will be outlined.
Ch I Analytical Methods • 9

Table I-2.—Symbols Used in Financial Analysis

a = accelerated depreciation multiplier (a = 1

for straight line; a = 2 for double-declining balance)

B(r,LN,t) = interest paid during year t on $1.00 of

debt paying interest r over LN years (defined in equation 12)

CRF(d,L) = capital recovery factor for a loan with

interest d payable over L years (defined

in equation 3)

d = consumer’s discount rate

d ’ = consumer’s discount rate in constant

dollars (1 +d‘) = (1 + d)/(1 + i)

D(a,DP,t) = permitted depreciation of $1.00 of initial

investment in year t given a permitted

depreciable lifetime of DP and an accelerated depreciation multiplier of a (defined in equation 22)

DEP(a,DP,R) = net present value of depreciation with

accelerated depreciation multiplier a,

depreciation period DP, and discount

rate R (defined in equation 29)

DP = depreciation period

E(t) = payments for energy made during year t

(evaluated in constant dollars valued at

the first year of the system’s operation)

f = fraction of initial value of system

financed with mortgage

FIX = fixed charge made by a utility or other

industry to cover Ievelized capital expenses and yield the desired rate of return

fb = fraction of utility plant financed with

bonds

f c = fraction of utility plant financed with

common stock

f p = fraction of utility plant financed with

preferred stock

i = annual rate of inflation

IN = fraction of capital value of plant paid for

insurance annually

INCOME(t) = gross receipts received by a system

owner during year t of a system’s operation

ITC = investment tax credit (fraction of capital

value of plant deducted from taxes in

first year of operation)

K O = installed initial cost of equipment

including inflation and interest during

construction. KO is evaluated in dollars

valued at the first year of the system’s

operation

K(t) = capital expended during year t of a

plant’s construction (evaluated in dollars

valued at the first year of the system’s

operation)

k, = muItiplier for determining the

capital-related component of the levelized PRICE paid by customers for energy

from the initial installed cost ●

k 2 = multiplier for determining the energy

component of the Ievelized PRICE paid

by customers for energy from the energy

cost in the first year of the system’s

operation*

ks = multiplier for determining the routine

maintenance component of the Ievelized

PRICE paid by customers from the cost

of routine maintenance in the first year

of the system’s operation”

k 4

(t) = multiplier for determining the

contribution of a major replacement

made during year t to the levelized

PRICE paid by customers given the cost

of the replacement in year t measured in

dollars valued during the first year of the

system’s operation*

L = period over which system costs are

measured

LN = period of loan

MO = routine operating costs in the first year

of the system’s operation

M(t) = major replacements made during year t

of the systems operation (measured in

dollars valued at the first year of the

system’s operation). For most years M(t)

will be zero

N = the system’s life in years

NC = number of years required to construct a

large plant or system

Nr = life of major replacements

PV(d) = present value of a cash flow given a

discount rate d (defined in equation 1)

PRICE = Ievelized annual price charged to the

customer

PT = fraction of initial capital value of the

equipment paid annually for property tax

r = interest rate paid on mortgages

R = commercial and industrial required rate

of return

RU = utility’s permitted rate of return (defined

in equation 32)

r b 

=

interest rate paid by utilities on bonds

= return paid by utilities on common stock

N

= return paid by utilities on preferred stock

S(R,L ) = annual amount paid by utilities into a

sinking fund to retire debt at the end of

LN years assuming that the fund is invested at a return of R (defined in equation 35)

t = the year of system operation under

consideration

T = net income tax rate (defined in equation

11)

T, = Federal income tax rate

Ts = State income tax rate

TAX(t) = income tax paid in year t

ð(t) = a switch function used for convenience,

b(t) = O unless t = O in which case ð(0) = 1

“NOTE: On the k,, k,, k,, and k, (t) multipliers, no primes indicate Federal financing, one prime indicates homeowner financing, two primes indicate conventional

commercial financing, three primes Indicate utility financing using normalized accounting, and four pr~mes indicate utility financing using flow-through accounting.

34-117 [) - -9 - J
70 ● Solar Technology to Today’s Energy Needs

The expenses occur in four separate categories:

CAPITAL-RELATED EXPENSES

The initial capital investment is called KO.

Since all of this investment is assumed to be

made in the first year, no discount is applied

and therefore the levelized capital costs can

be written as follows:

LEVELIZED CAPITAL COSTS = k 1 K0

(4)

k 1 = CRF (d,L)

where CR F(d,L) is the capital recovery factor

defined previously, L is the period over

which the system costs are evaluated and d

is the Federal discount rate. (The OMB circular states that for planning purposes, the

Government should use d = 10.0 percent, if

all expenses are expressed in constant, uninfIated dollars.)

ENERGY EXPENSES

Energy expenses must be discounted to

present value using the discount rate. If the

cost of energy in constant dollars in a year t

is called E(t), then the levelized energy expense is given by:

LEVELIZED COST OF (5)

PURCHASED ENERGY = k2 E(1)

t = l

where i is the rate of inflation.

O&M EXPENSES

For simplicity, it is assumed that the routine operating and maintenance expenses

(excluding energy costs) will not change during the life of the system if these expenses

are expressed in constant dollars. If these

constant expenses are called MO, the levelized annual O&M expenses are given by:

LEVELIZED OPERATING COSTS = k 3 MO

(6)

k 3 

= CRF(d,L)/CRF(d’,L)

d’= (1 + d) / (1 + i) -1

REPLACEMENT EXPENSE

It may be necessary to replace major

components during the life of the system. If

the cost of replacements made in the year t

(less the salvage value of the component

replaced) is called M(t), the levelized value

of replacement costs can be computed as

follows:

(8)

(Note that M(t) is zero for most years.)

PRICE

The total Ievelized costs of providing

energy services can then be written as

follows:

PRICE = (9)

L

t = l

Homeowner Financing

A calculation of the effective price paid

by a homeowner for energy generated by a

solar device which he owns requires adding

a number of complexities to the case just

described, although the overall components

of cost fall into the same four categories

and the final formula for levelized cost can

also be reduced to a simple linear equation

identical to equation (9).

CAPITAL-RELATED EXPENSES

The capital-related charges for a homeowner fall into four basic categories:

Payment on a mortage.—It is assumed that

the homeowner will finance a solar unit on a

new home with the same mortage used to

purchase the rest of the house, and that systems retrofitted to existing homes are
Ch I Analytical Methods ● 7 1

financed with “home improvement loans”

covering the fuII value of the improvement.

If it is assumed that the loan covers a fraction (f) of the equipment and that an interest

rate (r) must be paid for a period of (LN)

years, the annual mortgage payments are

given by:

ANNUAL (lo)

MORTGAGE PAYMENTS = f KO CRF (r,LN)

Income taxes.–The homeowner will be

able to deduct the interest paid on the

equipment and property taxes from his income when he computes his taxes. It is

assumed that the owner pays a net income

tax rate T. Since State taxes are deductible

from Federal taxes the net tax rate T can be

computed from the Federal tax rate Tf a n d

the State tax rate Ts as follows:

T = Tf (1–T s

) + Ts = Tf + Ts–T f Ts (11)

The interest in year t on the loan value fK O

wilI be given by:

(INTEREST ON

MORTGAGE PAID IN YEAR t = fKOB(r,

B(r,LN,t) =[(1+r)[- (r-CRF(r,LN)

(12)

L.N)t)

+

CR F(r,LN)]

Property taxes.— It is assumed that property taxes are charged at a rate which is

directly proportional to the initial value of

the instalIation, and that these payments are

given by:

PROPERTY TAXES = PT KO

(13)

where PT is the property tax rate.

Insurance.–It is assumed that the owner

pays insurance on the equipment at a rate

directly proportional to the initial value of

the installation and that these payments are

given by:

INSURANCE PAYMENTS = IN KO (14)

Using this notation, a down payment of

(1 – f)KO will be made in year O and the total

annual capital-related costs during year t

can be expressed as follows: (15)

CAPITAL

CHARGES (t) = KO [(1-f) CRF(d,L) +

fCRF(r,LN) - Tf(1+r)t-1 (r- CRF(r,LN )

+ CRF(r)LN) +(1-T)PT + IN]

and the levelized capital charges can then

be expressed as follows:

LEVELIZED CAPITAL CHARGES = k1 Ko (16)

d’ = (1 + d) / (1 + r) -I

ENERGY EXPENSES

The Ievelized cost of fuel and electricity

purchased by a homeowner can be expressed in terms of the price paid for these

items during the first year of the system’s

operation E(l). The equations are identical

to the ones developed in the previous case:

LEVELIZED COST OF

PURCHASED ENERGY

k'2~ = CRF (d)L)

(17)

= k'2~E(l )

L

t = l

O&M EXPENSES

If the cost of routine annual operating

and maintenance expenses (not including

the cost of purchased energy) during the

first year the system operates is called MO

,

the cost of O&M in the year t will be equal

to (I + i) tM O where i is the rate of inflation.

The Ievelized cost of O&M can then be expressed as follows:

LEVELIZED O&M COSTS = k3~ MO (18)

k '

3 = k3

where k3 was defined in equation (6).
12 ● Solar Technology to Today’s Energy Needs

The Ievelized price the homeowner pays

can then be written as:

(21)

the

price which is charged by firms other than

utilities for energy services. It is impossible

to construct a single procedure for evaluating the financing of all private firms, since

each has different sources of financing, is in

a different tax position, and has different

financial objectives. The procedure described below provides a simplistic way of

evaluating:

● The price which an owner of an apartment building charges for energy services (lighting, miscellaneous electricity,

heating, cooling, and hot water).

● The amount the price of a manufactured item is increased to pay for energy used by a manufacturing concern.

CAPITAL-RELATED EXPENSES

In computing the price, it is assumed that

equipment owners expect a fixed rate of

return on their equity and that all operating

and maintenance costs (including the cost

of purchasing fossil fuels and electricity) are

passed along directly to the customer. If the

investment in novel energy equipment is

perceived to involve a greater risk, the expected rate of return will probably be higher

than those expected from other areas of the

same industry.

There are three major differences between the financial analysis made for the

homeowner and the analysis which must be

made for commercial and industrial firms:

●

●

●

Depreciation of energy equipment,

fuel, and operating costs can be sub

tracted from gross income for tax purposes.

Investment tax credits may be available.

Insurance payments are tax deductible.

Depreciation. -The type of depreciation

permitted by the IRS depends both on the

type of business and on the nature of the

equipment involved. A ruling must be made

both on the system’s lifetime for depreciation purposes and on whether an accelerated depreciation technique will be permitted.

If a new building derives more than 80

percent of its revenues from apartment rental income, and if it has only a single owner,

the heating and cooling equipment in the

unit can presently qualify for “double

declining balance” depreciation. Buildings

with more than one owner are permitted

only a 1.25 declining balance. Most new industrial equipment can also qualify for double declining balance for tax purposes if its

expected life is greater than 3 years. A ruling

by IRS on solar equipment must be made.

For a first approximation it will therefore be

assumed that the equipment is treated like

conventional heating and cooling systems

for tax purposes. These assumptions can be

changed if other rulings are made by IRS,
and possibilities are examined in the policy

discussion.

The depreciation in year t will be called

D(a, DP,t)K O where a = 2 for double declining balance, a = 1.25 for 1.25 declining

balance, etc. Double-declining balance depreciation will be assumed in most cases.

This means that the owner can deduct twice

the straight-line depreciation calculated on

the basis of the depreciated value of the

equipment in the year the depreciation is

claimed (e.g. if a $100 asset has a 10-year

life, the first year deduction is 2 x $100/10

= $20, the second year deduction is 2 x

(100 – 20)/10, and so on. It is permissible to

shift from an accelerated depreciation technique whenever there

ing so. It is assumed

make such a shift.

D(a,DP,t) can be

follows:

is an advantage in dothat the investor will

written explicitly as

t O = the first year for which t is greater than or

equal to 1 + DP (l-l/a)

A shift is made to straight-line depreciation

when t = tO

. Notice that if a = 1 the shift is

made at the first year and the depreciation

is a simple straight line for the entire system

lifetime.

Tax Credits.–Some of the equipment

being examined may qualify for an investment tax credit. This credit can only be

taken in the first year of the system’s operation, and has been 10 percent of qualifying

capital for the past few years. When tax

credits are allowed, the calculations assume

that the owner is permitted a single-tax

credit equal to ITC x K O during the first

year of operation. The constant ITC is the

ratio of the credit obtained to the initial

capital value of the equipment (KO

).

Insurance Deductions.—Insurance payments can be subtracted from gross income

for tax purposes.

PRICE

The price charged by the owner of the

energy equipment can be calculated from:

(1) the annual payments which must be

made to cover capital and operating costs

(the payments made in year t are called

OUTLAYS(t)); (2) the gross income received

(income); and (3) the taxes paid (TAX(t)).

These items can be evaluated as follows:

where f = fraction of project financed by debt

(24)

TAX(t) = T(INCOME (t) -(1+i)t(Mo+M(t) + E(t) ) -

K O

(fB(r,LN,t) + D(a,DP,t) + PT + IN)

- (deductions for major replacements)]

As shown, the tax is reduced by KO

ITC in

the first year of operation. It is assumed that

the income from the project consists of a

constant charge for capital which permits

the owner to earn his desired rate of return.

The desired rate of return is called R and the

constant capital charge is called FIX. It is

also assumed that all operating costs, including the cost of purchased fuels, are

passed along to customers in the year in

which they are incurred. The routine annual

operating costs (excluding the cost of purchased energy) are called MO; the cost of

major items replaced during year t is called

M(t) which in most years is zero); and, the

cost of energy purchased in the year t is

called E(t). All of these costs are expressed in

constant dollars valued in the initial year of

the system’s operation. The income derived

from an investment in energy equipment

during year t can then be written as follows:

INCOME (t) = FIX+ (1 +i)’(Mo+E(t)) (25)
14 ● Solar Technology to Today’s Energy Needs

where i is the assumed rate of inflation. By

definition, if the owner charges rates which

yield an income equal to INCOME (t), the

owner is earning a rate of return R on his investment, and the present value of all cash

flows discounted using the owner-desired

rate of return R is zero. It can be shown that:

L (26)

(27)

+ IN + PT

(28)

R ‘=(1+R)/(l+r)-1

The net present value of depreciation

D(a, DP, t) over the depreciation period DP is

DE P(a,DP, R) and can be written as: (29)

o if d = o

1

DE P(a,DP,R)=

(31)

The Ievelized price paid by customers is

readily calculable once FIX is known since:

PRICE = k1" KO+ k'2 E(l)+ k'3 M O+

Utility Financing

(32)

[Mo + E(t)] (1+i)t

(1 + d)t

1

L (33)

The financing of utility projects is a complex process. Projects are of enormous

scale, many sources of funds are used, and a

network of regulations govern accounting

procedures. Financing varies greatly from

region to region because of different ruIings

by the State public utility commissions

which monitor utility financing. Furthermore, public and privately owned utilities

are financed in very different ways. The

following discussion presents a series of

simplified methods for approximating utility

accounting. A standardized procedure for

computing utility costs has been developed

in two recent analyses, and the methods

developed here are a somewhat simplified

version of these procedures. 3

4

CAPITAL-RELATED EXPENSES

Rate of Return.–The major difference between investments made by utilities and in3

The Cost of Energy From Utility-Owned Solar Electric Systems: A Required Revenue Methodology for

ERDA/EPRA Evaluations, June 1976 (ERDA/J PL -

101 2-76/3).

‘E PRI Technical Assessment Group, Tecbnica/

Assessment Guide, August 1977.
Ch I Analytical Methods ● 1 5

—

vestments made by the smaller organizations discussed previously is the source of

funds used for construction and operations.

utilities have three primary sources o f

funds: common stock, preferred stock, and

bonds. The fraction of a given facility

financed by each of these sources are called

fc

, fP, and fb, respectively. The rate of return

which a utility must earn to meet its obligations (Ru

) can be computed from those fractions and from the rates of return which

must be paid for each source of capital

(these are called r C

, rP, and rb). Note that

debt service is tax deductible, whereas stock

dividends are not.

(34)

R u =( 1-T)r b fb + rc fc 

+ r p fp

There is some dispute in the utility community about whether to reduce the cost of

debt by the factor I-T as shown in equation

(34).

The rates which can be earned by utilities

are controlled by public utility commissions

in each locality, and the return earned by

holders of common stock varies as a function of the rulings of these commissions and

the prevailing economic climate. For the

purposes of the analysis which follows, it is

assumed that the utilities are permitted to

earn returns equivalent to the average return paid over the past decade. In the case

of a municipal utility, the facility would be

financed entirely from bonds and no taxes

would be paid. Therefore in this case Ru =

rb where rb is the interest earned on the municipal bonds issued to finance the project.

Sinking Fund.– It is assumed that the utiIity

pays its stockholders and noteholders a uniform return on their investments during the

life of the plant and returns the entire principal borrowed when the loan is retired. In

order to provide for this final payment the

utility must set aside a “sinking fund, ”

which accumulates an amount equal to the

capital borrowed by the utility by the time

the plant is decommissioned. If the utility

can earn an amount R on the funds set aside

for this purpose, an adequate sinking fund

can be developed if an amount S(R,LN)KO is

set aside each year where:

(35)

S(R,LN) =

R

(1 +R)LN – 1

It is assumed in this analysis, that the rate R

that the utility can earn on the funds in the

sinking fund is equal to Ru

.

Plant Construction. -In the equation s

presented Up to this point, it is assumed that

the capital has been paid in one sum in year

t = O. utility devices, on the other hand, may

be so large that they require many years to

construct. Investors will expect a return on

their investment during the construction

period even though the plant is not earning

revenue. Utilities are currently permitted to

charge customers for the cost of capital tied

up during construction only after the plant

begins to generate power. (The allowances

vary from one regulatory jurisdiction to

another. ) This is done by including an

“allowance for interest used during construction” in the value of capital on whic h

the utilities are permitted to earn a return ,

For ratemaking purposes, therefore, the

capital value of the plant (KO

) used to compute the price charged to customers includes the cost of capital up to the time that

the plant enters service. If the outlays for

labor and equipment during year t are called

K(t) (where K(t) is given in constant dollars

valued in the year the plant begins operating), the value of the plant on which a

return can be earned (KO

) can be approximated as follows:

(36)

where NC is the number of years required to

construct the plant.

PRICE

Using this notation, it is possible t o
16 ● Solar Technology to Today’s Energy Needs

develop a simplified analysis of the flow of

utility assets:

(37)

OUTLAYS (t)=KO [PT+lN+f br b+f cr c+f PrP +

- KO (fbrb +PT+IN+ D(a,DP,t) )

– (deductions from major replacements)]

-KO ITC ð (t- 1 )

In this case PT includes ad valorem and all

other taxes not based on income. Using

methods described earlier it can be shown

that:

L

(39)

(41)

Throughout this analysis it has been assumed that utilities will use the rate of return Ru to discount future cash flows. In

fact, however, a recent survey of privately

owned utilities conducted by Consolidated

Edison Company of New York revealed that

only about 20 percent of the companies

surveyed used this formulation. The remainder used a rate of return which did not

reduce Ru by the tax savings resulting from

debt financing. This technique is used

because it results in a conservative analysis

of future risks. The higher discount rate

places a penalty on near-term capital investments and discounts future savings

more heavily.

The price charged by the utility depends

on the accounting procedures required by

local utility commissions. The two types

most commonly used are discussed below:

NORMALIZED ACCOUNTING

Most privately owned utilities employ a

procedure called “normalized” accounting.

In this procedure, customers are charged a

fixed price for capital in much the same way

as the conventional industrial procedures

discussed in the previous case. The utility is,

however, permitted to charge a rate for

capital as though it were depreciating its

facilities using “straight-line” depreciation

techniques, with the taxes actually paid

based on an accelerated depreciation schedule. Since all depreciation techniques result

in the same total amount of depreciation,

customers end up paying the same total

amount for electricity with this procedure as

if the utilities charged them on the basis of

the actual accelerated depreciation. This

procedure, however, permits collecting

more money from customers early in the

plant’s life and results effectively in a zerointerest loan from the customer to the utility. (These funds are used to finance new

construction but cannot be included in the

utility’s rate base. ) Accounting procedures

vary and the calculations which follow are

only intended to approximate the methods

actually employed by utilities.
Ch I Analytical Methods ● 1 7

An approximation of the income resulting

from normalized accounting is given by:

INCOME (t) = FIX’+ (1+i)t IMo+ E(t)]

(43)

A number of simplifications have been introduced into this accounting procedure.

The same capital value, KO

, is to represent

several different capital quantities:

–The value which must eventually be repaid to stockholders and bondholders

and for which a sinking fund must be

established,

–The depreciable value of the plant for

tax purposes,

–The value of the plant which is eligible

for investment tax credits,

–The value of the plant for ratemaking

purposes, and

–The insured value of the plant.

In practice, all of these values are different.

For example, in most cases, actual interest

outlays during construction are deducted

from income taxes in the year they occur.

This “interest during construction” cannot

be included in the depreciable value of the

plant when it enters operation and does not

qualify for an investment tax credit. This

value can be included in the value of the

plant for ratemaking purposes, however.

Another example is the value of the land

on which the plant is sited. This is part of the

value of the plant for ratemaking purposes

and its value must be included in the sinking

fund, but land is not depreciable and cannot

be used as a part of the depreciable value of

the plant for tax purposes. These distinctions are not large enough to affect the results of the approximate calculations used

here. The major difference between the

normalized accounting approach and the

standard procedure developed for unregulated industry is that the fixed capital

charge (in the case of normalized accounting) does not anticipate a return on the capital accumulated from accelerated depreciation early in the plant’s Iife.

– expenses for major replacements

Using this formulation of income with the

annual outlays computed earlier, the levelized annual value of the total cost of energy

perceived by customers is given by:

where

(46)
18 ● Solar Technology to Today’s Energy Needs

(47)

MUNICIPAL UTILITIES

Municipal utilities typically finance 100

percent of their plants with tax-exempt

bonds which in most cases can be sold with

interest rates considerably below the rates

charged for commercial bonds. (This advantage cannot be enjoyed if the creditBASELINE ASSUMPTIONS

In order to keep the number of variables

in this study down to manageable proportions, it was necessary to fix a number of

quantities at the onset. The following quantities are held constant throughout the

study.

INFLATION

All costs in this study are expressed in

constant 1976 dollars. To compute costs in

years other than 1976, an inflation rate

equal to 5.5 percent is assumed.

HOMEOWNER FINANCING

If lending institutions accept solar equip

ment as having no greater risk than conventional space-conditioning equipment, or if

solar devices represent only a smalI fraction

of the total loan, the cost of solar devices

can be included in the loan package financing the rest of the building, with rates of interest no different from those paid on nonsolar buildings. 1n such circumstances, loans

made for installing solar equipment on existing structures could be expected to cost

no more than conventional market homeimprovement or modernization loans.

If bankers feel that homeowners are

assuming substantial risk by investing in

solar equipment, loans will be more difficult

to obtain or will be obtained under terms

less favorable than mortages charged for

other types of equipment. A recent survey

indicated that in such situations lenders are

not likely to raise interest rates, but will insist on a larger down payment (or smaller

loan-to-value ratios). ’ A similar policy would

result if lenders felt that solar equipment

represented a high technical risk or would

be plagued by breakdowns and repair bills.

It is difficult to determine the circumstances

under which lenders would accept solar

equipment until the technology has conclusively proven itself through operating ex6Eva/uation of Alternative /ncentives for Overcoming Mortgage Market Constraints on the Commercia/

Acceptance and Use of Residential Solar Energy Technologies, NSF Grant APR75-18360, Interim Report ,

Dec 31,197 5
Ch I Analytical Methods ● 1 9

perience, In practice, the loan policies of individual lenders depends strongly on the

credit-worthiness of individual borrowers,

prevailing attitudes about the worth of various solar devices, and other intangibles,

Choosing a typical value for interest paid

on home mortgages is difficult because

rates have fluctuated substantially in recent

years The analysis in this report assumes

that an interest of 9 percent is paid on a loan

covering 75 percent of the value of the

house. The average interest rate paid for

new homes in the United States in 1975 was

9.01 percent (including initial fees and

charges), and the average loan-to-purchaseprice ratio was 76.1 percent. ’ It is assumed

that loans made for “home improvements”

wiII average three percentage points above

the rate for new purchases.

Income Taxes

It is assumed that the purchaser of solar

equipment for single famiIy homes has a taxable income (after deductions) of approximately $18,000. Standard Federal tax tables

for joint filing show taxes on incremental income at this level are paid at a rate of 2 8

percent. This is higher than the average U.S.

income in 1976 but approximates the taxable income of owners of detached residences.

State taxes vary widely, and several States

have no State income taxes of any sort. The

average rate of State tax payments for an individual with an income in the range shown

above is approximately 6.5 percent. 8 Thus,

the total tax paid by the individual in question on incremental income is assumed to be

34.5 percent.

Property Tax

It is assumed that the homeowner pays

property taxes to State and local govern7NE W’S, Mar 19, 1976, Federal Home Loan Bank

Board, table I

8.5tatlstical Ab~tract of the UnJted States, Department of Commerce, p 268 (Note Some State taxes

were a pproxl ma tecj when only a range of va I ues for

t,] x r,+t es were shown )

ments at a rate of 7 percent based on an

assessed valuation of 30 percent of market

value. This results in a net property tax rate

of 0.02 on the capital value of the house and

solar equipment. 9 10

Insurance

It is assumed that the homeowner can insure this solar equipment at rates equivalent

to ordinary property insurance which is $.25

per $100 of value.

RENTAL PROPERTIES

Statistics on the techniques used to finance rental property are difficult to assemble. Terms vary widely because of the different financial options of individual owners

and investing organizations. The situation is

complicated further by the fact that most

buildings are financed with several notes,

each with different interest rates and

maturity dates. Publicly available data on

the financing of rental property does not appear to have been compiled with as much

thoroughness as data on single family residential debts. Some data is available from

the American Council of Life Insurance,

which has compiled data on loans for residential buildings with values greater than

$100,000 made to owners of multifamily

apartments. I n 1975, the average interest on

such loans was 10.09 percent, in 1976, the

average interest was 969 percent, and the

rate fell to 9.33 percent in 1977 The average

“loan-to-value” ratio was 75 percent. ” The

computations which follow will assume that

in a “baseline” case, the apartment owners

will finance 75 percent of the property with

a loan paying 10 percent.

In some cases, apartment owners can be

expected to be reluctant to broaden their investments and purchase energy-generating

‘State and Local Finances – Significant Features,

AC I R 1973-74

1‘]1 97.2 Council of Governments Report

‘‘Statlstlcs prepared by tbe American Councl] of

Life Insurance provided to OTA by Betty Bancala

(ACLA), Mar 12, 1978
20 ● Solar Technology to Today’s Energy Needs

equipment which they may feel is outside

the conventional boundaries of their business. In an effort to isolate themselves from

fluctuating energy prices and the possible

effects of rent control, apartment owners

have frequently avoided owning and operating even conventional energy equipment

such as central boilers and air-conditioners.

Separate heating and cooling units have

been installed in each apartment, and the

utilities bill individual customers directly.

This practice is encouraged in the administration’s National Energy Plan.

Expected Rate of Return

Owners of real estate must earn enough

on their investment to compensate for the

added risk of these ventures as compared to

more secure and, in the case of apartment

properties, more liquid investments. The

yield on equity invested in real estate

depends heavily on the income tax position

of the investor, the favorability of financing,

the reception of risk, and expectations

about the resale value of the property. The

value of real estate has increased rapidly in

recent years, and a significant fraction of

the “rate of return” expected from such

property has come in this form. An investment company’s expected return will vary

widely as a result of all these variables, and

a single value cannot fairly represent the

market. It is necessary to examine a number

of possibilities in this area, and the following discussion is intended to provide at least

some direction in choosing rates of return.

An analysis of returns experienced by owners of apartment, office, and retail property

in the Washington, D. C., area during the

period 1968-74 indicates that returns of approximately 8.5 percent (after taxes) were experienced on buildings in the range of $30

million, with smaller projects earning approximately 1 percent more. 12 In the analysis which follows it is assumed that apartment owners earn 1 O-percent returns after

taxes.

1zMcCloud Hodges , Real Estate Consultant,

McLean, Va,, private communication,

It is quite possible, however, that the investors will expect higher rates of return on

the incremental equity invested in solar

equipment. Investing in conventional equipment to provide utility service to rental units

is a necessary part of construction costs.

Added funds for new energy equipment may

well be perceived as a higher risk investment

and be subjected to tests commonly applied

in other economic sectors.

A series of interviews with organizations

attempting to sell new energy equipment indicated a reasonably consistent pattern of

expectations about the return from equipment such as new heat-recovery systems and

heat pumps. It was felt that most investors

would expect the new equipment to “pay

for itself” in 4 to 5 years. This corresponds to

an investment paying 15 to 20 percent returns for a period of 10 years. It is, of course

crucial to understand the circumstances

under which solar equipment would be considered a routine part of rental property,

and the circumstances under which a large

rate of return would be expected for the

equipment. It is reasonable to suppose that

in the early stages solar equipment would be

required to provide substantial rates of

return for investors.

An average debt-to-value ratio for apartment buildings has been substantially more

difficult to determine. This is partly due to

the fact that loan amounts are typically

computed on the basis of an assumed “debt

coverage ratio, ” instead of on a fixed rule

of-thumb for downpayments. The debt coverage ratio is defined as the ratio between

the stabilized net income of the property

owner and the cost of paying the mortgage.

This ratio can be as low as 1.10 in cases

where a long-term Government lease makes

risk minimal, and it can be as high as 1.25 or

more in instances where occupancy is uncertain. Conversations with several bankers and

examination of recent loan packages indicate that assuming a debt-to-value ratio of

75 percent could be used as a “typical case”

to represent today’s market.
Ch I Analytical Methods ● 2 7

Tax Status

It is assumed that the owners of rental

property have a sufficiently high enough

taxable income to pay State and Federal

taxes at a combined rate of 50 percent. As

noted earlier, most apartments qualify for

double-declining balance depreciation; it is

assumed that equipment is depreciated with

double-declining balances over a depreciation interval of 15 years, regardless of the

actual lifetime of the equipment. Apartments do not qualify for investment tax

credits on energy equipment, and none are

assumed in the analysis.

Insurance and Property Taxes

Property tax and insurance rates are

assumed to be identical to the rates paid by

homeowners.

INDUSTRIES

It is assumed that an industry finances 30

percent of its investments in new energy

equipment with debt instruments paying 10-

percent interest rates.

Expected Rate of Return

As in the previous case, the rates of return

expected on novel industrial equipment will

depend critically on the perception of the

risks involved. In generaI, however, industries expect to recover capital on new equipment very quickly to ensure continued competitiveness in an economic climate which

may be changing rapidly. The Thermo-Electron Corporation recently surveyed a

number of chemical, paper, and refining industries and concluded that 50 percent

would invest in equipment if a 22-percent

return on investment after taxes could be expected. (See figure 1-3. ) In the following

analysis, it is assumed that industries use a

required rate of return of 20 percent to

determine the cost of energy generated by

onsite equipment.

Taxes

It is assumed that industries pay Federal

and State taxes at a combined rate of 50 percent. Most industries are able to use an investment tax credit granted during the first

year of a system’s operation; qualifying

property must be tangible, depreciable, and

must have a useful life of at least 3 years. 13

The amount of the credit has fluctuated

since it was first instituted, but it is currently

10 percent. This amount is assumed as the

“baseline” credit for computing industrial

costs.

UTILITIES

Utilities finance equipment primarily

from three sources: bonds, preferred stocks,

and common stocks. Statistics showing the

national average of utility fund sources are

shown in table 1-3.

Bonds

Bond financing is relatively inexpensive

compared with other sources of capital, but

there is a limit to the amount of capital

which can be raised from bonds. A bond is a

contract to pay a fixed amount to the holder

regardless of the utility’s income. A failure

to pay the required interest could, in principle, lead to bankruptcy of the utility. To protect themselves, lenders require that utilities

have an income sufficient to make debt payments even in times of economic hardship.

The most common measure of this margin

of safety is called the debt “coverage ratio, ”

which is defined to be the ratio of income

before taxes to annual debt payments. During 1974, the average privately owned utility

had a coverage ratio of 2.4. In practice,

lenders maintain these coverage ratios by

linking interest rates to them. Debt financing becomes prohibitively expensive or unavailable if debt service requires too great a

fraction of utility income. For the purposes

of this analysis, however, it is assumed that

utility debt remains at the current national

average of 53 percent, although utilities attempt to achieve a situation where only

’

13IRS publication 572, 1976 edition, p. 1.
100

80

60

40

20

Figure l-3.—Cumulative Distribution of ChemicaL Petroleum Refining, and Paper and Pulp Companies

Willing To Invest in Inplant Cogeneration Equipment Versus Internal Rate of Return on Investment

Rate of return (o/o)
Ch I Analytical Methods . 23

Table 1-3.—Summary of the Financing of Public-Owned Utilities in the United States 1973.74

—

1974 1973

.

I Long-term debt

A. Percentage of capitalization and retained earnings (1). . . . . . . . . 53.0 52.3

B.Average interest rate (2) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.3 5.9

C. Average rate paid on new debt issues (4) & (5) . . . . . . . . . . . . . . . . . 8.15 (January) 7.51 (January)

9.37 (December) 8.17 (December)

D. Times interest earned (3) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.4 2.6

II. Preferred stock

A. Percentage of capitalization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12.0 12.1

B. Average dividend rate (2) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.8 6.4

C. Average dividend rate paid on new issues (6)& (7). . . . . . . . . . . . . . 7.68-11.50 7.15-8.6

///. Common stocks and retained earnings

A. Percentage of capitalization and retained earnings (1). . . . . . . . . . 34.8 35.6

B. Percentage return on common equity (3) . . . . . . . . . . . . . . . . . . . . . 10.7 11.5

C. Common dividend payout ratio (3). . . . . . . . . . . . . . . . . . . . . . . . . . . 70.4 67.9

NOTES A; references are to Statistics of Pnvafdy Owmxf E/eCtf/CUfjljfjes In the u~ited Watt= for 1974 and 7973. published b the Federal power Commls

slon

(1} 1974, p XXII, (2) 1974, p XIX, (3) 1974 p XIV< (4) 1974, II XIII: (5) 1973, II XXVI; (6) 1973, p XXVIII, (7) 1974, p XVI

about 50 percent of their financing comes

from bonds. (See table 1-3.)

The average double-A bonds issued for

utilities during January 1974 paid 8.15 percent interest, and those issued in December

paid 9.37 percent. It is assumed that the interest paid on utility bonds will be 8.5 percent. A dramatic increase in the rates paid

by utilities has, however, created a situation

where the average interest rate paid by utilities on long-term debt is far less than the

cost of new debt. I n 1974, for example, the

average cost of debt to public utilities was

6,3 percent. ” The increase in the cost of

debt is due both to an overall increase in the

cost of bonds, and that the credit ratings of

many utilities have dropped in recent years

due to financial difficulties in the industry.

Bonds with lower ratings command higher

interest rates to compensate the investors

for the higher risks which they involve I n

January 1975, triple-A bonds paid 8.99 percent interest, double-A bonds paid 9.45 percent, A-bonds paid 10.37 percent, and BAAbonds paid 11.57 percent. A rate of 9 percent is used in the analysis.

14Statistlc$ of frl~ately Owned Eiectrlc Uti/\ties in

the United States, 1975, Federal Power Commls$lon, p

L, S-260

Stocks

After raising as much of its capital requirement as it can from internally generated cash and bonds, a utility will turn to the

stock market for the remainder. In general,

the rate of return paid to preferred stockholders is less than that paid for common

stock, and it is therefore assumed that the

utility wiII issue as much preferred stock as

possible. Since the preferred stock is similar

to a bond in that it imposes a contractual

obligation on the company to pay a fixed

fee at a specified time, there are limits on

the amount of capital which can be raised

from preferred stocks, In fact, many preferred stock issues explicitly limit the percentage of net worth which can be raised i n

this way in order to maintain an acceptable

level of confidence in the reliability of preferred stock payments, Preferred stocks

averaged about 12.2 percent of the total

outstanding stock of publicly owned utili tie: in 1973 (see table l-l), and this fraction

is assumed in the analysis. Rates paid for

preferred stock have risen sharply in recent

years for the same reasons, causing the rise

in the price of new debt. The average return

paid on preferred stock in 1974 was 6.8 percent, although new issues were sold for rates
24 ● Solar Technology to Today’s Energy Needs

varying from 7.68 to 11.5 percent. A rate of 9

percent is assumed in the analysis.

Any remaining capital requirements must

be met by issuing additional common stock

in the company. The feasibility of doing this

in a real market will depend strongly on the

perceived strength of the utility at the time

of issue, which will, in turn, depend on the

price-earnings ratio at the time.

The average return paid on common utility stock in 1974 was 10.77 percent. This may

not be an appropriate value to assume as a

return, however, since 1974 was a very poor

year for owners of utility stock. Table I-4 indicates the historic pattern of inflation and

rates of return on utility equity.

Earnings have averaged 7 to 8 percent

above inflation. Since it has been assumed

that inflation will average 5.5 percent, a 13-

percent return on equity is used to compute

utility costs.

Taxes

It is assumed that utilities qualify for the

lo-percent investment tax credit on all purchases, and that double-declining balance

depreciation schedules are employed over a

period of 30 years. Federal and State taxes

are assumed to have a combined effective

tax rate of 50 percent. Ad valorem, property

taxes, and other taxes are assumed to be 2

percent per year. ’s

15Op. cit. (ERDA/J PL-101 2-76/3).

Table l-4.–Historic Pattern of Inflation and Rates of Return on Utility Equity

1974 1973 1972 1971 1970 1969 1968 1967 1966

Earnings available for common stocka

. . .......10.7 11.5 11.8 11.7 11.8 12.2 12.3 12.8 12.8

GNP deflator b . . . . . . . . . . . . . . . . . . . . . ........10.3 5.6 3.4 4.5 5.5 4.8 4.0 3.2 2.8

(Earnings)-(inflation). . . . . . . . . . . . . . . . . . . . . . . . 0.4 5.9 8.4 7.2 6.3 7.4 8.3 9.6 10.0

a,qatjstjcs of private/y owned Electric Utilities in the United States 1974, FPG, P. XXIX.

bStatjstjca/ Absfracf Of the United States 1975, US. Department of COmmerCe, P. 416.
Chapter II

CURRENT AND PROJECTED

FUEL COSTS
Chapter II- CURRENT AND PROJECTED FUEL COSTS

Page

 Current Energy Prices. . . . . . . . . . . . . . . . . . . . . . 27

Estimates of Future Energy Prices .... .......30

Projections . . . . . . . . . . . . . . . . . . . . . . . . . . . . .31

Fossil Fuel Prices . . . . . . . . . . . . . . . . .......34

Electricity Prices. . . . . . . . . . . . . . . . . .......36

Other Projections . . . . . . . . . . . . . . . . .......38

LIST OF TABLES

Table No. page

1. 1976 Fuel Prices. . . . . . . . . . . . . . . . . . .......28

2. Model’s Assumed 1976 Electric Rate

Structure . . . . . . . ● . . . . . . . . . . . . . . . . . . . . . . .29

3. Simplifed Electric Rate Schedules. .. ......29

4. Constants for Brookhaven National Laboratory

Price Increase Projections. . . . . . . . . .......34

LIST OF FIGURES

Figure No. Page

1. Actual 1976 Residential Delining BlockRate Structure lncluding Fuel Adjustment. .28

Figure No. Page

2. 1976 Residential Electric Rate Structure

Used in Model . . . . .. .. .. .. .. ... ... .....30

3. Assumed Future Residential Natural

Gas Prices, Albuquerque . . . . . . . .. .......32

4. Assumed Future Residential Natural

Gas Prices, Boston . . . . . . . . . . . . . . .......32

5. Assumed Future Residential Natural

Gas Prices, Fort Worth . . . . . .. ... .. .....32

6. Assumed Future Residential Natural

Gas Prices, Omaha. . . . . . . . . . . . .. .......32

7. Assumed Future Residential Heating

Oil Prices, Albuquerque . . . . . . . . . . .......33

8. Assumed Future Residential Heating

Oil Prices, Boston . . . . . . . . . . . . . . . .......33

9. Assumed Future Residential Heating

Oil Prices, Omaha . . . . . . . . . . . . . . . . . . . . . .33

10. Assumed Residential Electriciy Rate

increases, Boston . . . . . . . . . . . . . . . .......33

11. Potential Marginal Costs of Baseload

Electricity in the Year 2000. .. .. .. .. ......36

12. Potential Marginal Costs of Baseload

Electricity in the Year 2000. . . . . . . . .......37
.

Chapter II

Current and Projected Fuel Costs

Anticipating the future cost of energy in the United States is an extremely

uncertain undertaking. The complex industry is in rapid flux, and the past is

an unreliable guide to the future. Prices will depend on:

●

●

●

●

●

the cost of developing and producing domestic fuel resources;

the price of imported fuels;

the cost of producing synthetic fuel substitutes;

externalities such as environmental regulations; and

regulatory impact, both explicit and implicit.

Confident estimates in these areas simply are not possible, although a

large number of the estimates can be supported. The predicted future price of

fuel can have a strong influence on both private and public decisions about

solar energy. Investments in solar and other conservation equipment will appear more attractive if energy prices are expected to rise sharply instead of

remaining constant or increasing gradually. Public perception of future

energy prices may be guided, to a large degree, by the Government’s behavior

on this issue. As long as the Government insists that energy prices will not

rise, the public almost certainly will make decisions on this basis.

CURRENT ENERGY PRICES

The prices charged during 1976 for residential and utility fuels in the four regions

examined in this study are illustrated in

table II-1. It should be noted that there is a

significant difference between prices paid

for residential natural gas in different parts

of the country ($3.18 per million Btu

(MMBtu) in Boston and $1.10 per MMBtu in

Kansas City in 1975), and the prices charged

for utility coal ($5 per ton in Albuquerque,

where access to mines is direct, and $25 per

ton in Boston, where transportation costs

are significant). In general, energy prices

demonstrate a greater geographic variation

than the total amount of sunlight available

for solar installations, and the two effects

may cancel each other out. In New England,

for example, insolation rates are relatively

low, but fuel prices are high.

The prices charged for electricity are

more difficult to summarize, since most utilities charge different rates in summer and

winter and use “declining block rates” to

define costs in each season. The actual residential rate schedules used in each of the

four cities in 1976 are plotted as a function

of monthly consumption in figure I 1-1, As

can be seen, electric prices vary greatly

around the country.

The rates used in evaluating the cost of

electricity consumed by different customers

are simplified approximations of the actual

prices charged. The assumed rate schedules

are summarized in table 11-2, and residential

rates are illustrated in figure 11-2. The schedules were prepared from the actual rates,

using procedures outlined in table II-3. Different schedules were applied, as appropriate, to residences, apartments, shopping

centers, and industries. Where different

summer and winter rates applied, the rates

were averaged by weighting each seasonal

rate according to the number of months in

the season. Complex rate schedules were

simplified with Iinear approximations in

some instances.

27
28. Solar Technology to Today’s Energy Needs

Table II-1.—1976 Fuel Prices

Residential consumer prices Average delivered contract price at

incl. applicable taxes a

utility electric plants, January 1976b

(mils/kWht) (mils/kWht)

Natural No. 2 Natural Residual fuel

Locatio n gas heating oil gas oil (No. 6) Coal

Albuquerque. . . . . . . . . 4.980 9.89 3

c

2.696 6.335 0.8601

(Dallas) (Mountain ) (New Mexico) (New Mexico) (New Mexico)

Boston . . . . . . . . . . . . . 10.87 10.40 5.669 6.171 4.239

(Boston ) (Boston) (Vermont) (Massachusetts )

Fort Worth . . . . . . . . . . 4.980 Not Available 2.966 6.010 0.9010

(Dallas) (West South Central) (Texas) (Texas) (Texas)

Omaha. . . . . . . . . . . . . . 3.747 9.57 3

C

2.365 5.474 3.276

(Kansas City) (West North Central) (Nebraska) (Nebraska) (Nebraska)

(Note The followlng conversion factors were used. 1 therm = 2930 kWht, 1 gallon No 2 oil = 40.64 kWht; 1 kWht = 3413 Btu)

a~efa,l p,lC~~ ~n~ ln~~xes of FUe/S afl~ urlll(les Res/derrt/a/ use, Bureau of Labor Statlsf!cs, u S Dept of Labor, March 1976

b Federal power Commission News Release No. 22363, May 19, 1976

cMonfhly Energy Rev~ew FEA, fvIay 1976, p 6Q

Figure II.1 .—Actual 1976 Residential Declining Block-Rate Structure Including Fuel Adjustment

MWh/yr.

o 6 12 18 24 30 36 4 2 4 8 54 60

140

120

100

80

60

4 0

20

0 500 1000 1500 2000 2500 3000 3500 4000 4500 500 0

SOURCE: Federal Power Commission, June 1976. Monthly kWh used
Ch. II Current and Projected Fuel Costs ● 2 9

Table II-2.—Model’s Assumed 1976 Electric Rate Structures

City Loads (see previous table)

Albuquerque

SFH Bill = {

1.60 + .02928 X kWh . . . . . . . . . . . . . . . . . . . . . . .,,.,. kWh<650

6.41 + .021876 X kWh . . . . . . . . . . . . . . . . . . . . . . . . . . .kWh>650

TNH, LR, HR, SC BiII = {

102.50 + .011043 X kWh . . . . . . . . . . . . . . . . . . . . . . . . . D<50

10 + 3.85 X .011043 X kWh . . . . . . . . . . . . . . . . . . . . . . D>50

Boston

SFH, TNH Bill = {

2.23 + .0558 X kWh . . . . . . . . . . . . . . . . . . . . . . . . . . . . . kWh61000

22.027 + .03603 X kWh . . . . . . . . . . . . . . . . . . . . . . . . . . kWh>1000

I

1.60 x No. units + .29 x D +

.0629 x kWh . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . kWh<200 x D, and kWh<12,000

1.60 x No. units + .41 x D +

LR, HR Bill = .0623 x kWh . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . kWh>200 x D, and kWh<12,000

1.60 x No. units + .29 x D +

.0625 X kWh . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . kWh<120 x D, and kWh>12,000

1.60 x No. units + 1.838 x D +

.0472 X kWh . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . kWh>120 X D, and kWh>12,000

82 + 3.664 X D + .03707 X kWh D<8O0, and kWh<300

84.44 + 3.664 X D + .02893 X

kWh . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . D<800, and kWh>300

SC Bill = { 3013.50 + 3.433 x D + .03707 X -

kWh . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . D>800 and kWh<300

3015.94 + 3.433 X D + .02893 X

kWh . . . . . . . . . . . . . . . . . . . . . . D>800, and kWh>300

Fort Worth

SFH Bill = {

1.69 + .0368 X kWh . . . . . . . . . . . . . . . . . . . . . . . . . . . . . kWh<200

3.95 + .02548 X kWh . . . . . . . . . . . . . . . . . . . . . . . . . . . . kWh>200

D Bill = 1.65 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . D<8 1.65 + 1.85 X (D-8).. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . D>8

“D-500” = D<500

. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . D>500

TNH, LR, HR, SC Bill = D Bill + 92.40 + .01703 x kWh . . . . . . . . . . . . . . . . . . . kWh<50,000 + 100 X (“0-500”)

D Bill + 943.90 + 01313 x

kWh + 1.703 X (“D-500”). . . . . . . . . . . . . . . . . . . . . . kWh>50,000 + 100 X (“D-600”)

D Bill + 1600.44 + .01043 x

kWh<100,000 + 200 X (“D-500”)

kWh + 3.016 X ("D-500").. . . . . . . . . . . . . . . . . . . . . kWh>100,000 + 200 x (“D-500")

Omaha

SFH Bill = {

3.91 + .0289 X kWh . . . . . . . . . . . . . . . . . . . . . . . . . . . . . kWh<800

9.65 + .02174 X kWh . . . . . . . . . . . . . . . . . . . . . . . . . . . . kwh>800

TNH, LR, SC Bill = {

93.88 + .0218 X kWh . . . . . . . . . . . . . . . . . . . . . . . . . . . . kWH<7,500+ 300 x D

147.21 + 2.13 X D + .0147 X. . . . . . . . . . . . . . . . .

kWh. . . . . . . . . . . . . . . . . . . . . ... , . . . . . . . . . . . . . . . . . . . . kWh>7,500 + 300 X D — . .— Source Off Ice of Technology Assessment

Table n-3.-Simplified Electric Rate Schedules

City Fuel adjustment– Actual electric rate schedules from which simplified schedules are developed

(electrlc utility) (mils/kWh) for each case modeled (Effective date) ———

Single family

—. 

house (SFH) —

Albuquerque 3.043 Schedule #l

(Publicc Service residential service

Company of New (May 23, 1975)

Mexico)

Boston 19.1 Residence rate B

(Boston Edison (Oct. 17, 1975)

Company)

Fort Worth 2.13 Rate R

(Texas Electric residential service

Service Co.) (Dec. 3, 1975)

Omaha 2.07 Schedule #10

(Omaha Public residential service

Power District) (March 1, 1976)

Ra~ Ddfa SI, F [, I, I t, FPC 13(,r{ ,iu f PI ,+( r Jun(> 1976

8 Unit

townhouse

(TNH)

Schedule #3

general power

service

(May 23, 1975)

Rate B

Rate G

general service

Schedule #30

general service

(March 1, 1976)

36 Unit

low rise

(LR)

No. 3

Apartment

house rate C

(Oct. 17, 1975)

Rate G

No. 30

— — -

196 Unit

high rise

(HR) _

No. 3

Rate C

Rate G

No. 30

Shopping

center

(Se)

No. 3

General

service rate

(Oct. 17 1975)

Rate G

No 30
30 ● Solar Technology to Today’s Energy Needs

Figure ll-2.—1976 Residential Electric Rate Structure Used in Model

1

1920

1680

1440

240

0

0 1000 1500 2ooo 2500 3000

SOURCE: Office of Technology Assessment. Monthly kWh used

ESTIMATES OF FUTURE ENERGY PRICES

As indicated, methods to project future

energy prices are quite inexact. A variety of

organizations have published estimates of

the future prices of energy and, as may be

expected, the results vary greatly. As a

result, rather than relying on a simple projection to provide a set of energy prices for

comparison, a range of estimates has been

used. These include:

1. no increase in energy prices in constant

dollars;

2. residential energy price projections

generated by Brookhaven National Laboratory (BNL); and

3. a projection chosen arbitrarily higher

than the BNL forecast.

The results of these estimates are illustrated in figures II-3 through II-10 for the

four cities examined. This set is used to demonstrate the sensitivity of price in the analysis. It is intended not to represent most

probable future energy prices, but a set of

projections representing several plausible

forecasts of future energy prices. The choice

of these bounds is explained below, along

with a description of how the curves were

obtained.
Ch. II Current and Projected Fuel Costs ● 31

The Brook haven National Laboratory

(BNL) is responsible for preparing the Department of Energy’s (DOE) projections of

future energy prices. However, because the

Federal Energy Administration (FEA) had responsibility for setting “near-term” energy

policy, the Brook haven modelers were required to use FEA’s energy price projections

through the year 1985. The BNL projections

used here were received in July 1976, and at

the time were BNL’s “baseline ” (high

nuclear power) residential energy price projections. ’ There is no single “standard” set

of BNL energy price projections, as a number of scenarios with different assumptions

about the future have been run and have

yielded differing results. Furthermore, BNL

is constantly updating its energy price projections as new data become available. 3

Even DOE’s energy price forecasters admit that al I forecasts are necessarily speculative. However, the more sophisticated

forecasters, such as BNL, take their initial

guesses and run them in supply/demand

models to see if the resulting mix of fuels

looks “reason able.” If the initial guess

results in an unlikely mix of fuels being

burned (all natural gas and no oil or coal, for

example), the future energy price guesses

are revised and the model is run again. This

process is repeated untiI they have a

‘‘reason able-looking” set of future energy

price guesses which result in a “reasonableIooking” future energy use mix. ’ The result

of these analyses is a set of energy price

ratios indicating the growth in energy prices

as a function of the current price of energy.

BNL concurred that:

1, The exponential curve fit (described

below) is an acceptable way of extrapolating their energy price ratios to

beyond the year 2000.

‘ Resldentlal energy price projections from BNL supplied by Eric HIrst, Oak Ridge National Laboratory,

)UIY 1976

‘D Behllng (BNL), private communication, j uly 19 ,

1976

‘1 bid

‘M Beller (BNL), private communication, July 19,

1976

2.

3.

Applying these price ratios to actual

1976 prices of energy in various regions

of the country is an acceptable way of

projecting future energy prices in each

location.

Applying the corresponding residential

‘D Behling (BNL), op clt

*The time constant (T,) of 283 years for the three

high projections, IS a reasonable choice since it is

close to the typical lifetime of generating plants,

mines, oil- pumping rigs, etc
32 ● Solar Technology to Today’s Energy Needs

Figure II-3.—Assumed Future Residential

18

16

14

12

10

8

6

4

2

0

Natural Gas Prices

Albuquerque

1976 1980 198 5 1990 1995 200 0

Year

A. Unregulated natural gas in 1976

B. LNG in 1976

C. Synthetic gas from coal @ $40/ton

D. Synthetic gas from coal @ $20/ton

SOURCE: Office of Technology Assessment.

Figure n-4.-Assumed Future Residential

Natural Gas Prices

Boston

12 -

10 “

8 -

6 -

4

2

1976 1980 198 5 1990 1995 200 0

Year

A. Unregulated natural gas in 1976

B. LNG in 1976

C. Synthetic gas from coal @I $40/ton

D. Synthetic gas from coal @ $20/ton

SOURCE: Office of Technology Assessment.

F

5“

i

igure ll-5.— Assumed Future Residential

Natural Gas Prices

Fort Worth

16 –

14 –

12 –

10 –

8

-

6

-

4 -

2 -

I

I

Natural Gas Prices

Omaha

.05

1976 1980 1985 1990 1995 2000

Year

A. Unregulated natural gas in 1976

B. LNG in 1976

C. Synthetic gas from coal @ $40/ton

D. Synthetic gas from coal @ $20/ton

SOURCE: Office of Technology Assessment.
Ch. II Current and Projected Fuel Costs ● 3 3

Figure ll-7.— Assumed Future Residential

Heating Oil Prices

Albuquerque

.02

.01

Source: Office of Technology

Assessment

Figure ll-8.— Assumed Future Residential

Heating Oil Prices

1976 1980 198 5 1990 1995 2000

Year

Figure ll-9.— Assumed Future Residential

Heating Oil Prices

Omaha

Year

Figure II-10.— Assumed Residential

Electricity Rate Increases
34 ● Solar Technology to Today’s Energy Needs

this curve, and the results shown in table

11-4. The table also shows constants chosen

to yield prices higher than the BNL projections.

Table n-4.-Constants for Brookhaven

National Laboratory Price Increase Projections*

PRICE (m)

PRICE (1976) t — ——. o T r

BNL electricity. . . . . . . . . . . . . . 1.62 1952.8 28.33 4

BNL gas . . . . . . . . . . . . . . . . . . . 2.89 1965.7 24.33 4

BNL oil . . . . . . . . . . . . . . . . . . . 1.71 1951.2 28.33 4

2x cost projection . . . . . . . . . . . 2.00 1956.4 28.33 4

5x cost projection . . . . . . . . . . . 5.00 1979.7 28.33 4

10x cost projection . . . . . . . . . . 10.00 1973.0 28.33 4

— —

“These constants are defined in equation (1) In the text. The price ratto

shown In the f}rst column IS ihe constant dollar ratio between an assumed

future ‘stable” price of energy of the type shown and the price paid In 1976

For the purposes of this study, the fivetimes-cost (5 x ) projection was chosen. A

discussion of the factors making up the cost

of the principal energy sources follows this

section to demonstrate the plausibility at

the 5 x projection.

FOSSIL FUEL PRICES

Natural Gas

Current natural gas prices in most of the

country are a result of Federal and State

regulatory actions, which control the price

from the wellhead to the ultimate user. The

large cost variations between localities, as

evidenced by comparing Boston an d

Omaha, result from the differences in transportation costs and the volume of supplemental gas resources (propane-air mixture, synthetic natural gas from petroleum

products, and liquefied natural gas) that

must be used to meet demand. These latter

supplies are only partially price regulated,

and their costs to the gas distributor more

nearly reflect the real incremental costs of

new suppIies. However, these costs are averaged with that of flowing gas so the ultimate

user does not see this incremental price.

Current regulated gas prices range from

about $0.20 to $1.49 per million Btu

(MMBtu) at the wellhead and from about

$1.85 to $4.70 per MMBtu (1976 prices) delivered to residences, depending on when

the gas was dedicated to the interstate market.

6 In some parts of the country (the intrastate market), natural gas prices are not

regulated and new contract gas sells for

about $1.00 to $2.00 per MMBtu at the wellhead. ’ The average price of natural gas to

residences in the intrastate market area is

about $2.35 per MMBtu. 8 Future gas prices

will be determined by the costs of bringing

in new reserves as existing fields are depleted, developing synthetic natural gas

from coal and liquids, and providing imported Iiquefied natural gas. Although precise estimates for 1985 and 2000 are not

possible at present, arguments can be made

which show that the range chosen is reasonable.

Gas from new reserves in the interstate

market was priced by the Federal Energy

Regulatory Commission (formerly the Federal Power Commission) at $1.45 per MCF at

the wellhead in 1977. However, as previously stated, new gas at the wellhead is selling

for up to $2.00 per MMBtu where not regulated. Synthetic natural gas (SNG) from

petroleum products (naphtha and propane)

is currently priced at anywhere from $3.00

to $4.20 per MMBtu at the pIant gate.

Although no plants to produce synthetic gas

from coal have been built, estimates are

that gas from such plants will cost from

$4.00 to $6.00 per MMBtu ($4.50 to $7.50 per

MMBtu delivered to residences) if coal costs

$20.00 per ton. 9 10 If the cost of coal doubled to $40.00 per ton, SNG prices would increase by approximately $1.50 per MMBt u

resulting in a delivered residential price of

‘Quarter/y Report of Gas Industry Operations,

American Gas Association, Third Quarter, 1977.

‘Federal Energy Regulatory Commission, News Release FE-69, Nov. 24,1977.

8Quarter/y Report of Gas /ndustry Operations, o p

cit

‘Gas Supp/y Review, American Gas Association,

vol. 5, January 1977, pp 9-10.

‘“Richard A. Tybout, Pub/ic Uti/ities Fortnight/y,

VOI 99, Mar. 31, 1977, p 17.
Ch. II Current and Projected Fuel Costs • 35

$6.00 to $9.00 per MMBtu. The current price

of gas imported as a Iiquid in cryogenic

tankers (liquefied natural gas or LNG) ranges

from about $1.75 to $2.90 per MMBtu delivered to the pipeline. 11 Although the above

prices, which are indicative of the marginal

costs of new supplies, are presently rolled

into the cost of flowing gas from existing

wells, the total price will more nearly equal

the marginal cost as the latter depletes.

When transportation and distribution

costs (about $0.50 to $1.50 per MMBtu) are

added to the above prices, the result is a

range of marginal prices from $2.25 to $9.00

per MMBtu. Although these are current

prices, the upper end of the range already

reaches or exceeds the 5 x ceiIing prices in

the year 2000 for all cities except Boston

(see figure II-4). As stated earlier, a considerable portion of Boston’s gas is made up

of supplemental supplies, and current prices

there are much closer to marginal cost of

new supplies. However, if synthetic natural

gas (SNG) from coal is included, an upper

price of $9.00 per MMBtu (delivered) is obtainable, which approximates the 5 x ceiling price in Boston in the year 2000. It appears that the set of 5 x ceiling curves for

natural gas is at least plausible.

Oil

A similar analysis can be developed for

oil. The present average price of domestic

oil is about $1.50 per MMBtu ($8.75 per barrel) at the well head. 2 Uncontrolled oil is

about $2.40 per MMBtu and imported oil

costs about $2.25 to $2.60 per MMBtu. 13 

Residential heating oil currently costs about

$3.35 per MMBtu delivered ($0.46 per gallon), This is about 30 percent above the

price of crude oil, reflecting the costs of

refining, transporting, and distributing the

fuel oil.

Future oil and gas prices will depend on

the cost of producing and transporting hy1‘Gas Supp/y Review, American Gas Association,

VOI 5, February 1977, pp 10-11

‘

zMonthly Energy Review, DOE, November 1977, p

72

‘Jlbld , Pp 72, 76

drocarbons from new sources and decisions

made by petroleum exporting nations. The

present price charged for oil from domestic

sources can be approximated by the price of

uncontrolled oil, $2.35 per mill ion Btu, [t

has been estimated that oil produced from

advanced recovery techniques at existing

sites may cost as much as $4.30 per million

Btu ($25 per barrel) before the supply of oil

from these resources begins to fall rapidly.14

The cost of imported oil will probably be the

largest factor in determining oil price over

the next 10 to 15 years. Although there is no

way to be certain that these prices will continue to increase from their present levels of

$2.25 per MMBtu, the continuing growth of

world demand and the likely peak in production around 1990 make it improbable

that prices will fall. Prices for oil produced

from coal and oil shale can only be approximated, as no operating plants exist. As with

SNG, these prices are subject to considerable uncertainty. In an analysis performed

by ERDA (now DOE) in March 1976, shale oil

prices of $2.50 per MMBtu were obtained.

However, this study indicated that estimates

of $3.25 per MMBtu had been made by

others. The report also noted that their calculation could range as high as $4.00 per

MMBtu, depending on financing assumptions. 15 Oil from coal was not estimated in

the study, but the similarity between these

processes and production of SNG from coal

allows the same price range ($4.00 to $6.00

per MMBtu) to apply.

The price of delivered residential heating

oil is presently about 30 percent higher than

crude oil. The range of costs quoted above,

$2.25 to $6.00 per MMBtu, is therefore

equivalent to $3.15 to $8.00 per MM Btu, or

$0,45 to $1.10 per gallon for delivered residential heating oil. These prices bracket the

5 x ceiling price in the year 2000 for all of

the cities (see figures I I-7 through 11-9) in

1

4 Fnhancecl 0;/ Recovery in the United States, Office of Technology Assessment, U S Congress, Washington, D C., January 1978.

I 5/JrOpOse~ S ynrltetic Fue/s Corn mere ia I Demonstration Program: Fact Book, ERDA, Washington, D C ,

March 1976
36 ● Solar Technology to Today’s Energy Needs

question, even before any real increase between now and 2000 is taken into account.

The plausibility of this 5 x ceiling again appears justified.

Coal

The price of coal varies enormously

around the country depending on the distance over which the coal must be shipped,

heat content, and sulfur content (which

determines the amount of pollution which

will be released by burning), and a variety of

other factors which determine its burning

properties. Contract prices paid for coal by

utilities vary from about $4.00 per ton in

North Dakota to nearly $40.00 per ton in

New Jersey. ”

Future prices will depend both on the extent to which the price of coal rises to meet

the increasing price of competing fuels, and

the extent to which environmental restrictions are imposed. If utilities are allowed to

use western coal without flue gas desulfurization (FGD) technologies to meet air quality standards, the average price of coal

would be lower than if they used eastern

coal and FGD devices. Estimates are that

sulfur cleanup will add as much as $0.60 per

MMBtu to the price of coal. 17

Based on this and on current coal prices, a

range of $1.00 to $2.50 per MMBtu is not unreasonable. It should be noted that no coal

prices as such are included in the price projections in figures II-3 through II-10. Coal

will show up in the price of electricity as it

has already appeared with respect to synthetic gas and oil. The sensitivity of electricity prices to coal prices will be discussed in

more detail below.

ELECTRICITY PRICES

The two major components of electricity

prices are the cost of fuel and the capital

cost of the powerplant. The relative signifi1‘Annua/ Summary of Cost and Qua/ity of Stearn-

[/ectric P/ant Fue/s, 1976, Staff Report by the Bureau

of Power, Federal Power Commission, May 1977

1

‘National Energy Outlook, Federal Energy Administration, February 1976, p F-6

cance of either depends on the fuel used.

Fuel costs are much more significant for oilfired plants than that for coal or nuclear,

since oil is two to five times more expensive

on a Btu basis. The interaction between

these two factors is shown in figures II-11

and II-12 which show the cost of electricity

sold at the generating plant (busbar cost)

and the average electricity sales price,

delivered to the customer, as a function of

the following variables:

●

●

●

the installed cost of the generating facility in dolIars per kw;

the cost of fuel burned in the facility

(coal, oil, or gas); and

the “capacity factor, ” defined as the

average percentage use of the facility’s

capacity.

Figure II.11 .—Potential Marginal Costs of

Baseload Electricity in the Year 2000

(75 Percent Load Factor)

Annual escalation in installed cost

(above inflation)

O% 2% 3% 4% 5% 6%

10

8

6

4

o 500 1000 150 0 2000 2500

c.-

Installed cost in 1976 $/kWh

Assumptions

–75% load factor –1976 Installed cost $500/kWh

–35% efficiency in generation and transmission

–Transmission and distribution cost $300 to $400/kWh

–Operating costs (exclusive of fuel) = $0.01/kWh

–Capital cost 0.15

SOURCE: Office of Technology Assessment,
Ch. II Current and Projected Fuel Costs ● 3 7

Figure ll-12.— Potential Marginal Costs of

Baseload Electricity in the Year 2000

(50 Percent Load Factor)

Annual escalation in installed cost

(above inflation)

o% 2% 3% 4% 5%

about $0.035 per kWh results from figure

11-11. It must be noted that this is the cost of

baseload electric power, i.e., that produced

by a large plant operating at a capacity factor of about 75 percent.

Utility loads fluctuate, however, and

I I I

I

o 500 1000 1500

Installed cost in 1976 $/kWh

Assumptions

–50% load factor –1976 installed cost $500/kWh

– 35% efficiency in generation and transmission

–Transmission and distribution cost $300 to $400/kWh

–Operation

–Operation

–Operating costs (exclusive of fuel) = $0.01/kwh

–Capital cost 0.15

SOURCE: Office of Technology Assessment.

In all cases it has been assumed that th e

plant is 35 percent efficient (including al l

losses in transmission and distribution). The

delivered electricity costs includes, among

other factors, the cost of building and operating a network of transmission and distribution Iines

Coal Powerplants

Coal-fired plants presently on order cost

about $500 per kW, including flue gas desulfurization devices. 8 Using present utility

coal prices of about $1.00 per MMBtu

($20.00 per ton) and a capacity factor of 75

percent, a delivered electricity price of

la~he Economic and Social Costs of Coa/ and

Nuc/ear E/ectric Generation, National Science Foundation, Washington, D C , March 1976, p 12

crated will need to come from faciIities

which can adjust their output rapidly (on the

order of minutes to hours) to meet these

fluctuations. These are typically smaller

steam turbines (less than 100kW), combustion turbines, diesel engines, or hydroelectric storage systems, and are relatively expensive to operate. The cost of this intermediate and peak load electricity is about

1.35 to 3 times that of baseload electricity. ”

The total cost of electricity is the weighted

average of the base, intermediate, and peakload electricity, and is about 40 percent

higher than the baseload price. Therefore,

$0.035 per kwh for baseload must be adjusted for a total cost to the customer of

about $0.049 per kWh. A further adjustment

is needed, since the rates to different classes

of customers are not the same. I n 1975, residential customers paid about 15 percent

more per kWh than the average to all customers. 20

The future price of electricity will depend

on the escalation rate of powerplant capital

costs and fuel. For example, it can be seen

from figure 11-11 that a 3-percent-per-year

escalation rate, above inflation, will cause a

$500 per kw plant to cost $1,000 per kW by

the year 2000. If this is coupled with a real

price rise in coal from $1.00 to $2.00 per

MMBtu, the delivered cost of baseload electricity becomes $0.057 per kWh.

Applying these adjustments produces a

total marginal cost in the year 2000 of

$0.092 per kwh delivered to a residential

customer. Previous discussion has already

shown this coal price to be plausible (it is

191977 ~a~jonal Energy Outlook, (Draft), Federal

Energy Administration, Washington, D C , January

1977, Appendix C, p. 19.

Zostat;stjcal yearbook of the E/ectric Uti/it y Industry,

Edison Electric Institute, New York, N Y., October

1976, p. 54.
38 . Solar Technology to Today’s Energy Needs

being paid by some utilities today). There

are no generally accepted estimates at this

time for the projected capital cost increase.

The actual rate will have a substantial effect

on electricity prices from coal-fired plants

and I S, therefore, one of the major uncertainties in assessing the relative economics

of alternative energy systems.

Nuclear Powerplants

Another major uncertainty is associated

with the cost of nuclear-generated electricity. The possible changes in plant capital

costs are even more crucial in this instance

because fuel costs do not contribute as significantly as in the case of coal. The many

studies on the relative marginal costs of new

nuclear and coal-fired electricity have

reached no definitive conclusion. It is likely

that percentage changes in capital costs will

be similar for both coal-fired and nuclear

plants, since the largest component is the

construction cost, which is relatively independent of the type of plant built. As a

result, nuclear costs will be more affected

by capital cost escalations because nuclear

power is more capital-intensive.

Another controlling item in the relative

costs is the relative fuel costs and the associated environmental and safety features

peculiar to each fuel cycle. This means that

if nuclear electricity prices are to be significantly lower than the $0.092 per kWh previously calculated, assuming a 3-percent

real increase in capital costs, the price of

nuclear fuel must not increase significantly.

However, present knowledge about moderately priced U3O 8 resources and serious

problems in developing a breeder reactor

make it likely that nuclear fuel prices will

continue to climb.

With regard to electricity, the 5 x ceiling

curve loses plausibility only if electricity

prices remain near their present marginal

costs. This means either no significant real

increase in capital costs (below 3 percent) or

the continuation or decrease (to compensate for any rise in capital costs above 3 percent) of present fuel costs Again, it is not

known what will occur in this context, but

the fact that there are major uncertainties

means that the 5 x ceiling cannot be precIuded.

OTHER PROJECTIONS

InterTechnology Corporation.–Several

other price projections have appeared recently, in addition to those quoted above.

To complete this discussion, a review of

these are given for comparison. In a report

on the economic potential of solar thermal

energy to provide industrial process heat,

InterTechnology Corporation assumed a

series of real escalation rates to obtain price

estimates for the year 2000 of $2. I 4 per

MMBtu for coal, $9.20 per MMBtu for oil

(approximately $1.25 per gallon for delivered fuel oil), and $8.02 per MMBtu for

natural gas, all in 1976 dollars. 21 The latter

two are equal to or greater than the 5 x ceiling price used in this study. The coal costs

correspond to coal at $43 per ton which, if

coupled with plant capital costs of $1,000

per kW, produce residential electricity of

about $0.093 per kWh.

Battelle Columbus Laboratories.–ln a

similar study, Battelle Columbus Laboratories came up with estimates for the year

2000 of $4.00 to $6.00 per MMBtu for

natural gas, $5.00 to $6,50 per MMBtu ($0.70

to $0.90 per gallon) for residential home

heating oil, and $1.50 to $2.50 per MMBtu

($30 to $50 per ton) for coal delivered to

utilities. ” Except for natural gas in Boston,

these prices also bracket the estimated oil

and natural gas prices in the year 2000 from

the 5 x ceiling.

Federal Power Commission (FPC).-ln a

report by the Bureau of Natural Gas of the

FPC (now the Federal Energy Regulatory

Commission (FE RC)), energy prices delivered

to residences of $4.16 per MMBtu for

natural gas, $3.58 per MMBtu for fuel oil

21 ArM/ySIS of the Economic Poterrtia/ of So/ar Therma/ Energy to Provide /ndustria/ Process t/eat, InterTechnology Corporation, Warrenton, Va , February

1977

22 Survey of the Applications of Solar Thermal Energy

Systems to /ndustria/ Process Heat, Battelle Columbus

Laboratories, Columbus, Ohio, January 1977
Ch. II Current and Projected Fuel Costs ● 39

($0.050 per gallon) and $0.035 per kWh for

electricity (alI in 1976 dolIars) were projected for the year 2000.23 These are national averages, and no means to allocate

them by region was given. It is not likely

however, that regional adjustments would

bring the prices near the 5 x ceiling in any

of the four cities under consideration. These

projections assume that all crude oil prices

will remain at the present level of imported

crude, $2.32 per MM Btu. Any increase in

this price will cause a corresponding increase in the other prices.

~ J The future CI t Na tura I Gas” Economic Myths, Regu/a tory Rea /ltles, Federa I Power Corn m isslon, Bureau

of Natural Gas, November 1976

Federal Energy Administration (FEA).–A

final set of price projections is that developed by FEA (now DOE) in the draft of the

7977 National Energy Outlook.24 Although

only estimated to 1985, they can still be

used for comparison to that date. Their

results (in 1976 dollars) are $3.72 per MM Btu

for fuel oil ($0.52 per gallon), $2.78 per

MMBtu for natural gas, and $0.049 per kWh

for electricity. These prices are based on imported crude oil prices of $2.25 per MMBtu,

and are those delivered to residential customers. In nearly all cases these are close to

the 5 x ceiling curve.

241977 Nat;ona/ Energy Out/ook, (Draft), Federa I

Energy Administration, Wast-llngton, D C , j anuar}

1977, Appendix C, p 19,
Chapter Ill

CALCULATION OF

BACKUP REQUIREMENTS
Chapter III.- CALCULATION OF BACKUP REQUIREMENTS

Page

Control Strategies for Cogeneration Systems.. 43

Cogeneration System With Electric Backup .46

Cogeneration With Fossil Fuel or Biomass

Backup . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 51

A Computer Analysis of Cogeneration . . . . . . 52

Calculation of Collector Performance . . . . . . . 52

Appendix Ill-A-Proof of Valve Opening

Sequence . . . . . . . . . . . . . . . . . . . . . . . . . . . .65

Appendix hi-B-Computer Program Listings ..66

LIST OF TABLES

Table No. Page

1. Sample Input . . . . . . . . . . . . . . . . . . . . .. .....53

2. Sample Output . . . . . . . . . . . . . . . . . . . . . . . . . . 54

LIST OF FIGURES

Figure No. Page

1. The Problem. . . . . . . . . . . . . . . . . . . . . . . . . . . 44

2. Simplified System Diagram .. . . ... .......45

3. Cogeneration System With Grid Backup ...47

4. Cogeneration System With Fossil Fuel

Backup . . . . . . . . . . . . . . . . . . . . . . . . .......52

5. Entries to Collector Subroutines COLL1,

COLL2, and COLL3 .. ... . . . . . . . .. .......56

6. Flow Diagram for Entry Point No. 1 to COLL1,

COLL2, and COLL3 . . . . . . . . . . . . . . . . . . . . . 56

7. Flow Diagram to Computing Hourly Collector

Output Using COLL1 . . . . . . . . . . . . ....... .58

8. Flow Diagram for Computing Hourly Collector

Output Using COLL2. . . . . . . . . . . .. .......60

9. Sectional View of Parabolic Trough

Collectors for Shading Computation .. ....61

10. Typical Collector Efficiency Curve . .......63

11. Flow Diagram for Computing Hourly Output

of a Heliostat Field . . . . . . . . . . . . . . . . . . . . . 64
Chapter Ill

Calculation of Backup Requirements

The calculations presented in the previous chapter required an analysis of

conventional and solar energy equipment operating in real environments. T h e

techniques used to perform such an analysis were discussed generically in

previous chapters. The following discussion reviews the analytical method in

some detail. The Fortran programs used to perform the calculations reported

elsewhere in this study are based on the methods described in this chapter

and are reproduced in full in appendix III-B.

The analysis of system performance requires three basic steps:

1.

2.

3.

Determine the onsite energy demand of the building (In the case of residences, this includes heating, cooling, hot water, and miscellaneous

electrical demands.)

Determine the out put of solar collectors.

Determine the fraction of the on site energy demand that can be met from

solar energy directly or from storage and the fraction that must be supplied from external energy sources (utility electricity, gas, or oil).

These three steps were performed for each hour of the year using

measurements of the air temperature and available sunlight recorded during

1962 (1963 in the case of Boston). The calculation of the heating and cooling

requirements of buildings was based on: the external temperature; an

assumed pattern of occupancy and appliance use; and, assumed thermodynamic characteristics of the buildings. A program (E-cube) developed by

the American Gas Association was used to convert the weather data and

building descriptions into an hourly estimate of the demand for heating and

cooling. Chapter V discusses the assumptions made about the buildings, and

the assumptions made about patterns of occupancy, appliance usage, hot

water demands, etc.

The performance of collectors was discussed generically in chapter Vlll of

the first volume and the methods actually used in the analysis are discussed

in the final section of this chapter.

A critical question in the operation of a solar energy system is the amount

of backup energy required and the pattern of this backup demand. Assessing

the performance of an integrated system is a complex problem, however, and

techniques have not yet been developed for optimizing the performance of

such systems. The next few pages discuss techniques for approximating the

optimum performance of several tyyes of solar cogeneration systems including the optimum operation of Possible combinations Of storage equipment.

CONTROL STRATEGIES FOR COGENERATION SYSTEMS

Minimizing the energy required to operate both solar and fossil-fired cogeneration

or total energy systems requires a careful

control strategy. For example, it is necessary

to: 1) optimalIy allocate the space-conditioning load between electrically powered

heating or cooling equipment and heatdriven equipment (e.g., electric versus absorption chilling for heat pumps versus

direct heating); 2) determine the optimum

ratio between thermal energy and electric

energy produced by the cogeneration
44 . Solar Technology to Today’s Energy Needs

engines; 3) determine the best strategy for

charging and discharging storage; and 4)

determine the best strategy for buying

energy from or selIing energy to an electric

utility or other backup power source. (Optimizing this last choice requires considering

how the cogeneration strategy affects costs

everywhere in the utility, which is a much

more complex problem than the one addressed here.) In general, the more flexible

the system, the less backup the system will

require since complex controls can ensure

that the system is operated as close as possible to the thermodynamic optimum for providing the necessary work. Greater flexibility and sophistication of controls often

mean an increase in system costs, and the

economic merits of these control systems

will need to be determined on a case-bycase basis. The problem of optimizing system designs and control strategies taking

full account of all of the real choices and

constraints has not been fully solved. All

that is offered here is a reasonable technique for approaching an optimum allocation, More work needs to be done in this

area.

The following discussion presents algorithms for minimizing fuel use for a variety

of different types of equipment. In most

cases, controls for providing the kind of

switching called for in the calculations are

not now available; however, there is no

reason to believe that such controls could

not be developed if a demand for the systems emerged. Control systems can probably be manufactured quite inexpensively

using modern electronics. Unfortunately,

the control systems used on contemporary

cogeneration systems have been relatively

primitive, and there are few standardized

designs.

Figure Ill-1 illustrates the general problem. Energy enters from three sources: 1)

high-temperature heat from a solar collector, 2) high-temperature heat from fossil fuel

available as backup, and 3) electricity used

as a backup. Three kinds of energy demands

must be met: 1 ) demands that can only be

met electrically (e. g., artificial lighting),

which is called EEE; 2) demands that can be

met either with electrical equipment or with

thermal energy (e.g., refrigeration can be

achieved with an electricalIy driven compressor or with thermally driven absorption

equipment, and space heating can be

achieved using thermal energy directly or

with electric heating), which is called QSH;

and, 3) loads that can be best met with

direct thermal energy when it is available

(e.g., domestic hot water or process heat),

which is called QP.

Figure Ill-1.—The Problem

Gnd Loads which

electridy can only be

met electrically

I I

 (EEE) I

I I 1

The problem can best be understood by

following the flow of energy from the initial

source of high-temperature energy (QH

) to

the demands, examining the decisions that

must be made at each point. The first choice

needed is whether the high-temperature

energy should be sent to the engines or be

used directly. Figure III-2 shows valve #1

which splits the high-temperature heat sending ßQH to the engines and (1 – ßQH to the

thermal loads where ß represents the valve

setting. The high-temperature heat enters

the first engine and is converted into an

electrical output of ßQHql, where ql is the

efficiency of the first engine. Some of the

energy not converted to electricity is available as heated fluids. In a completely general case, two waste heat streams may be

available: a “low-quality” waste heat stream

at a temperature too low for use in a bottoming cycle; and, a “high-quality” stream,

which can be used in a second engine. In the

calculations that follow, the ratio between
Ch. III Calculation of Backup Requirements ● 4 5

the energy available as “high-quality” heat

and the electrical output of the first ‘engine

is called al, and the ratio of the energy available as “low-quality” heat to the electrical

output of the first engine is called az.

Figure III-2.—Simplified System Diagram

If a second, or bottoming cycle, engine is

available, a choice must be made about the

optimum use of the high-quality waste heat

stream. The second valve can be used to

send part of this energy to the second engine

and part directly to thermal loads. The setting of this valve is indicated through the

variable ~. When T is 1, all of the highquality waste heat is sent to the secon d

engine.

With this notation, the net thermal (QT

)

and electrical (E) output of the system can

be written as follows:

Here q, is the efficiency of the second

engine. The problem becomes one of minimizing QH for fixed energy demands E and

Q T

. If there is no thermal demand, clearly

the optimum valve settings are P = 1 and

~ =1. It can be shown that as therma l

demands increase, the best strategy will use

the following procedure: 1) leave P = 1 and

~ = 1 until the waste heat generated in this

way cannot meet the thermal demands, 2)

reduce the energy entering the secon d

engine (i. e., T <1 ) while leaving @ = 1 until

the thermal demand cannot be met with

~ =1, 3) meet additional thermal demands

by leaving ~ = O and reducing ~. (See appendix I I l-A.)

The method for determining QH

, /3, and ~

for a given E and QL~ is as follows:

If Q L ~ ~ ~, E/(1 + ~, 7?2), then

~=1

1

Q H ~ E/(~Jl + (x,~J)

(3)

If ~, E/(1 + ~,TIJ gQL < (u, + CYJE, then

@=l (4)

-Y = [E(a, + cxJ– Q,l/[cxl (Q, q, + E)]

If (a, + a,) E <Q~, then

~ = E~E(l - ~! (~1 + ~J) + q, QL]

= 0 (5)

Q; = E/@q%

Another layer of complexity now has to

be added to describe optimum use of E and

QL to meet the demands EEE, QSH, and QP.

The QSH load can be met electrically or

thermally. The performance of the electric

units is described by the electric coefficient

of performance COPE. Similarly, the coefficient of performance for the thermal unit is

called CO PA.

If COPA > ql (COPE + (C Yl + Q,) COPA), it

is more efficient to use high-temperature

thermal energy directly than to run it

through the heat engine and use the waste

heat and electricity. If this condition is not

true, it is more efficient to meet some of the

space-conditioning load (QSH) electricalIy,

If two engines are available, the best use of

the high-quality waste heat must be determined (e. g., is it more efficient to run it

through the second heat engine or to use it

directly?). If q,COPE > COPA, it is more efficient to run the high-quality waste heat

through engine #2 and then use the electricity generated to meet the space-conditioning load instead of using the high-quality

waste heat directly (through COPA) to meet

the space-conditioning load.

The availability of storage equipment

adds another dimension of complexity.

Three types of storage are possible in cogeneration systems: 1) high-temperature storage; 2) low-temperature storage; and 3) electric storage. It is assumed that storage is

never charged with backup power except in

the cases where backup fossil heat is used to

meet electric needs and excess waste heat

produced in the process is available to
46 ● Solar Technology to Today’s Energy Needs

charge the low-temperature storage.

Low-temperature storage should not be

charged directly from collector output; it is

only charged when there is excess waste

heat or when there is overflow from hightemperature storage. The use of high-temperature energy is minimized if all available

energy in low-temperature storage is used

before any high-temperature energy is used.

High-temperature energy is kept in reserve

since storing energy in this high-quality form

maximizes the flexibility of using the available energy. A special problem arises when

both batteries and high-temperature storage

are available. It is assumed that batteries

will be more expensive than high-temperature storage and therefore batteries should

be kept charged whenever possible to maximize their use. This in turn assumes that the

batteries were sized in an optimum way.

When the high-temperature storage is filled,

the overflow is sent to be stored in low-temperature storage. When low-temperature

storage is filled, the overflow is discarded in

a cooling tower or in some other way. If it is

possible to sell excess electricity to an electric utility grid, however, this analysis assumes that an attempt is made to use the

amount of high-temperature energy that exceeds the capacity of high-temperature storage to generate electricity for sale. The

amount of electricity that can be sold i s

limited by the maximum generating capac -

ity specified for the engines. I n no case is

electricity sold when high-temperature storage (when available) is not filled to capacity.

It should be noticed that in the analysis

displayed here, it has been necessary to

specify the hierarchy with which the storage

units are charged and discharged. The priorities for using energy are: 1 ) meet onsite energy demands; 2) charge batteries; 3) charge

high-temperature storage; 4) sell electricity

to the grid; and, 5) charge low-temperature

storage. In some cases meeting the electrical requirements results in a situation

where low-temperature storage is charged

because excess waste heat is available. The

priorities for discharging storage are: 1 ) discharge low-temperature storage; 2) discharge high-temperature storage; and, 3) discharge battery storage. Given this set of

priorities, it is possible to optimize the use

of available energy. While a reasonable case

can be made for the priorities specified, it is

entirely possible that system performance

could be improved with a more sophisticated strategy. Solving this problem, and

thereby allowing an optimum choice of storage types and capacities, would require that

economic factors be considered along with

the analysis of energy use. Such an optimization has not been attempted in this

study.

It can be seen that optimizing a generalized cogeneration system can be complex.

The following sections present a detailed

description of the logic used in a computer

program designed to simulate the performance of optimized systems (a listing of this

program is in appendix I I l-B). The logic depends on the type of backup energy available.

COGENERATION SYSTEM WITH

ELECTRIC BACKUP

Figure III-3 shows the most general form

for a cogeneration system which relies entirely on an electric utility for backup. As

the loads must be met either from the output of the solar collectors, storage devices,

or by backup electricity purchased from the

grid, COPE and EHWEFF (the efficiency of

the electric hot water heater) must always

be non-zero. In a system with electric

backup, energy from the collectors or

storage is used to meet onsite energy

demands with the following priorities: QP

loads, QSH loads, EEE loads.

In the calculations, the system is optimized for each hour of the year. At the beginning of each hour the problem is as follows: Loads EEE, QSH, and QP must be met;

the amount of energy in storage is known,

and, the amount of high-temperature energy

from direct solar energy is known. The problem is one of efficiently using the stored

energy and the direct solar energy, and mini-
Ch. III Calculation of Backup Requirements • 47

Figure III-3.—Cogeneration System With Grid Backup

mizing the energy that must be purchased.

The first step is to meet as much of the

process load QP (and the space-conditioning

load if COPA is non-zero) as possible with

the energy available in low-temperature

storage. If only part of these loads can be

met from low-temperature storage, the process load QP is met first and any remaining

energy is used for the QSH load.

The second step is to determine whether

enough high-temperature energy is avaiIable

to meet any QP load remaining after step

one. AvaiIable high-temperature energy is

the sum of the energy in high-temperature

storage and the energy available directly

from the collector. If the QP loads cannot

be met by high-temperature energy (the remaining QP is called QP‘), high-temperature

storage is set to zero, and electricity is purchased from the grid in order to meet the remaining loads. The backup electricity which

must be purchased in this case (EBU) is given

by:

EBU = EEE + QSH + QP‘/E HWEFF (6)

where EHWEFF is the efficiency of the electric heater used to provide energy for the remaining QP loads [e. g., an electric hot water

heater). If the amount of high-temperature

energy exceeds QP one of three paths must

be taken depending on the relative values of

COPA, COPE, q,, q~, a,, and CXz.

A Case Where Thermal Energy

Cannot Be Used To Meet the

Space. Conditioning Load

If the available high-temperature energy

exceeds the process load, it may be possible

to meet some of the electrical demands

using the avaiIable high-temperature energy.

A check must first be made to determine

whether it is possible to meet the QSH loads

with thermal energy (i.e., whether COPA is

non-zero). It is assumed that for heating purposes, COPA is always 1.0; therefore COPA

can only be zero for a cooling load. If the

QSH load cannot be met thermally; a check

is then made to determine whether the optimum approach is to use alI available hightemperature thermal energy to generate

electricity and set /3 and T to minimize the

output of thermal energy (subject to the

constraint that the remaining QP load is

met). The available high-temperature thermal energy consists of all energy in high-
48 ● Solar Technology to Today’s Energy Needs

temperature storage and the energy available directly from the collectors.

A check must then be made to determine

whether this results in the output of the first

engine exceeding the maximum generating

capacity specified. If the maximum is exceeded, it is necessary to recompute ~, ~,

and the amount of high-temperature energy

used with the constraint that the electricity

reaching point 1 in figure II I-3 is equal to the

maximum capacity of the first engine.

The next check that must be made is to

determine whether the electricity generated

now exceeds onsite demands for electricity.

These onsite demands consist of: 1) the remaining QP loads; 2) QSH loads; 3) EEE

loads; and, 4) charging the batteries at the

maximum rate allowed by the power conditioner capacity specified. If the electricity

that could be generated during the hour in

question exceeds these onsite demands, it

might be possible to sell electricity to the

utility. A check must first be made, however,

to determine whether selling electricity

would result in a situation where the hightemperature storage unit was not filled to

capacity at the end of the hour. If high-temperature storage would not be full, the

amount of energy entering the engines and

the valve settings are adjusted to reduce the

amount of electricity and leave the hightemperature storage completely filled.

With this check the sequence is completed and the problem can be solved again

for the next hour.

A Case Where Thermal Energy Is Used

To Meet the Space= Conditioning Load

The previous discussion was limited to

cases where QSH could not be met with

thermal energy. If the following inequality

holds:

COPA > q, (COPE + COPA (CY, + a,)) (7)

it is more efficient to meet the QSH load s

with direct thermal energy than it is to meet

these loads with a cogeneration approac h

where both thermal (CO PA) and electrica l

(COPE) equipment are used to meet thermal

demands. This case can be treated using a

method that is completely analogous to the

case explained previously. AI I that is

necessary is to define an “effective process

load” QP’ and an “effective QSH load”

QSH’ as follows:

QP’ = QP + QSH/COPA (8)

QSH’ = O

All other steps follow as described above.

A Case Where Using Thermal Energy

To Meet the Space-Conditioning Load Is

More Efficient Than Using Electricity

Generated by the Second Heat Engine

If the following conditions hold:

VI (COPE + ‘COPA (cY, +CY2)) <COPA (9)

COPA >q,COPE

it is more efficient to meet QSH loads with

direct thermal energy from the high-quality

waste heat stream than it is to generate electricity with the second engine and use the

electrical conversion unit characterized by

COPE. Generating electricity with the first

engine and using this electricity in the electrical conversion unit and all available

waste heat to meet QSH demands thermally

is more efficient than using the available

high-temperature energy directly to meet

the QSH demands.

The first step is to use all energy available

in low-temperature storage to meet the QP

and QSH demands. The second step is to determine whether the high-temperature energy available (i.e., the solar energy received

directly during the hour plus any energy

available from high-temperature storage;

this sum is called SOLE in the remainder of

this discussion) is sufficient to meet the remaining QP load. If the remaining QP cannot be met in this way, QP is reduced by the

available energy and backup electricity

must be purchased. The amount purchased

can be computed using equation (6).

If the available high-temperature energy

is greater than the remaining QP, a somewhat complex procedure must be used to

determine the optimum valve settings. The
Ch. III Calculation of Backup Requirements ● 4 9

steps follow the sequence as outlined i n

equations (3) through (5), where an attempt

is made to use alI avaiIable high-temperature energy.

It is first determined whether sending all

of SOLE through the first engine and all

high-quality waste heat through the second

engine (i. e., -y = 1 and ß = 1 ) produces

enough waste heat to meet the thermal

loads. If the condition:

(SOLE) qla, > QP + QSH/COPA (lo)

holds, all QP and QSH loads can be met

with Iow-quality waste heat. ~ = 1 and ß =

1 are the best valve settings, and the calculations can proceed to test whether engine

maxima are exceeded.

If the inequality in (10) does not hold, it is

necessary to send some of the high-qualit y

waste heat directly to the thermal loads or,

equivalently, the value of ~ must be les s

than 1. (The theorem proved in appendi x

I I I-A shows that it is better to adjust ~ tha n

to adjust ß). If the condition:

SOLE q, (CYl + a,) >QP + QSH/COPA (11)

holds, then the QP and QSH demands can

be met entirely with thermal energy without

the need to divert any high-temperature

energy from the input of the first engine, although some high-quality waste heat must

be diverted from the second engine. The

valve settings are then given by:

ß = 1 (12)

SOL Ey,(a, + CY2) – QP - QSH/COPA

~=

SOLE qlcrl

If the condition shown in equation (11) is

not met, it is necessary to meet some of the

QSH loads with electricity. The condition

specified in equation (9) implies that it is

more efficient to use high-temperature energy in the first engine and run the electricity

through an electrical converter with COPE

than to use it directly through the thermal

conversion equipment characterized by

COPA. The next step, therefore, is to determine whether it is possible to meet the QP

load with valves set so that ß = 1 and ~ = O.

This is possible if the following inequalit y

holds:

SOLE ql(al + a,) >QP (13)

Some QSH loads may be met thermall y with

the remainder met electrically from the output of the first engine or (if necessary) from

backup electricity.

The amount of QSH that can be met thermalIy (QCT) is given as follows:

(14)

does not

QP loads

QCT = [SOLE q,(a, + cr2) – QP] COPA

If the inequality in equation (13)

hold, it is not possible to meet the

without diverting some high-temperature

energy from the input of the first engine. In

this case all of the QSH loads must be met

electricalIy from the output of the first heat

engine (or, if necessary, from backup electricity) and the optimum valve settings are

as follows:

(The quantity ß will never be zero since it

was necessary to determine that SOLE was

greater than QP in order to reach the sequence of tests just described. )

Having determined the optimum valve

settings it is again necessary to determine

whether the use of SOLE with the optimum

valve settings resuIts in a situation where the

first engine is required to produce electricity

at a rate which exceeds the specified maximum capacity (ENGMAX). If the following

inequality holds,

the engine maximum is exceeded and it is

necessary to readjust the valves.

The new valve settings are computed
50 . Solar Technology to Today’s Energy Needs

following a sequence of tests similar to

those indicated in equations (10) through

(16):

A)

ß = 1 (17)

B)

If QP + QSH/COPA<(a, + a,) ENGMAX

ß = 1 (18)

E NC MAX(cx, + a,} QP-QSH/COPA

7

=

a, ENGMAX

c)

If QP + QSH/COPA >(cx, + CXJ ENGMAX

QP < (cY, + a,) ENGMAX (19)

QSH < (ENGMAX - EEE)COPE +

(ENGMAX( a, + a,) – QP)COPA

Then ß = 1

70=

The third test involving the miscellaneous

electrical load (E E E) is necessary to ensure

that there is enough electrical output to

meet the QSH loads, which are not met thermalIy.

D)

If QP + QSH/COPA >(x2 ENGMAX (20)

QP <(a, + a,) ENGMAX

QSH >(ENCMA)( - EEE)COPE +

ENGMAX (a, + a2) – QP(COPA)

Then

ß = [COPA(ENGMAX)] /

[q 1QSH +q,COPEIEEE-ENG MAX] +

COPA [QPq, + ENGMAX(1 -(a, + a,) q,)]

-y = 0

E)

If QP>(cY, + CY,) ENGMAX, then (21)

ß

ENGMAX

=

ENGMAX(l-ql(al + a,))+ q,QP

70=

In each case a check must be made to determine the amount of electricity available

for charging the battery.

With this, the correct valve settings have

been determined. As before, however, a

check must be made to determine whether

using the specified settings will leave the

high-temperature storage filled. If the hightemperature storage is not filled at the e n d

of the hour, and if the use of the optimum

valve settings results in a situation where

electricity would be sold to the utility, the

system should be adjusted to use less hightemperature energy. (A similar recalculation

is required if excess electricity cannot be

sold to an electric utility grid. ) The first step

in such a recalculation is to determine the

valve settings that would be used if the system met only the minimum electrical demands. This will be called EOUT where

EOUT = EEE + (the maximum amount of electricity

which can be placed in the batteries) (22)

The maximum amount of electricity that

can be put in the batteries is the smaller of

the following two quantities: 1 ) the specified

capacity of the power conditioner; and, 2)

the difference between the maximum specified battery capacity and the amount of

electrical energy stored in the battery at the

beginning of the hour.

The valve settings, which optimize production in the case where the system only

produces electricity for EOUT, can be computed in the following sequence of steps:

A)

If QP + QSH/COPA < cY, EOUT/(1 + alq,)

Then ß = 1 (23)

71=

B)

If QP + QSH/COPA > EOUT (CY, + a,) (24)

Then

ß = 1

(a, + (x,) EOUT – QP - QSH/COPA

7

=

al[EOUT + q2 (QP + QSH/COPA)]

c)

If QP + QSH/COPA EOUT(CY, + a,) (25)

QP s EOUT(CX, + (X2)

QSH < (EOUT - EEE) COPE +

(E OUT (cY, +a,) – QP)COPA

Then ß = 1

~=o

D )

If QP + QSH/COPA> EOUT(cx, + a,) (26

QP < EOUT(U, + a,)

QSH > (EOUT – EEE) COPE +

(EOUT (a, +aJ – QP) COPA

Then ß and ~ are given by equation (20) using EOU T

instead of ENGMAX,

E)

If QP (a, + CYJ EOU T (27)

Then

ß

EOUT

=

EOUT (1 – q,(a, +cx,)) + q,QP

70=
Ch. III Calculation of Backup Requirements • 57

With the valve settings calculated in equations (23) through (27), it is possible to

calculate the minimum amount of high-temperature energy that must enter the system

to meet the loads. If the difference between

the amount of solar energy produced during

the hour and this minimum amount can be

placed in high-temperature storage, the

computation is complete for the hour. If

high-temperature storage would be exceeded, another step must be taken. The

amount of high-temperature energy available after the high-temperature storage is

filled can be calculated and the optimum

technique for using this energy computed by

using equations (10) through (21 ) (assuming

that electricity can be sold). If no electricity

can be sold, the excess high-temperature

energy is transferred to the low-temperature

storage. The low-temperature storage is

filled to capacity and the remaining energy

discarded.

A Case Where Using Electricity To Meet

the Space-Conditioning Load Is Always

More Efficient Than Using Thermal Energy

If the inequality:

COPA< rjIzCOPE (28)

holds, it will be more efficient to meet the

QSH loads using electricity from the second

engine than it will be to use thermal energy

to meet QSH loads directly. The thermal

units characterized by COPA will, therefore,

only be used if CYl is sufficiently large to

justify the instalIation of thermal conversion

equipment. The basic procedure followed in

this case is identical to the one described

previously with small differences resulting

from the relative values of COPA and

qlCOPE. The steps which are equivalent to

equations (1 O) through (15) are as follows:

A)

If SOLE qI, cY, >Qp (29)

Then ,13 = 1

~=1

(It should be noted that if COPA is not zero

and SO LEqlaz > QP, any “excess” lowquality waste heat is used to meet the spaceconditioning load.)

B)

If SOLE q,((xl + a,)z QP > SOLE qla, (30)

Then ß = 1

SOLE q,(cx, + a,) – QP

7

=

SOLE q,a,

c)

If QP SOLE q,(cxl + a,) (31 )

Then ß = SOLEql(al + a,)- QP

SOLE [q,(CY1 + CY,) -1]

70=

The remainder of the calculation can be

readily derived following this pattern.

At the end of each hour, the net amount

of electricity and low-temperature thermal

energy produced from the high-temperature

inputs and valve settings can be determined.

These are used to meet the EEE, QSH, and

QP loads. Any remaining low-temperature

energy is placed in low-temperature storage.

Any remaining electricity is placed in the

batteries or sold to the utility if the batteries

are filled. Onsite demands that cannot be

met with the onsite power are met by purchasing electricity.

COGENERATION WITH FOSSIL FUEL

OR BIOMASS BACKUP

Figure II I-4 illustrates a completely general cogeneration system, which is not tied

to a utility grid but is backed up with a fossil

or biomass fuel source. Notice (although not

shown in figure 3) that in the general case

there are three different kinds of boilers: 1 ) a

boiler used in the system providing backup

to the heat engine (this could be a coal-fired

steam boiler to back up a solar-powered

steam engine, the burner efficiency in the

backup unit used in a Stirling engine, etc); 2)

a boiler efficiency for the QSH loads (this

could be the burner efficiency in an adsorption chiller), and 3) the boiler used to produce QP.

The logic of the fossil backup case is very

similar to the logic employed in the electrically backed up system and details are

not shown here. The program which per-
52 . Solar Technology to Today’s Energy Needs

Figure III-4.—Cogeneration System With Fossil Fuel Backup

I

forms the necessary calculations is reproduced in appendix III-B. The major differences between the fossil and the electrical

case are:

●

●

●

Either COPA or COPE (but not both)

can be zero in the case of fossil backup.

It is assumed that the loads will be met

at all times. If an engine size is specified which does not permit meeting the

loads, the calculation performed in this

analysis will correct the initial estimate

as necessary.

In some cases high-temperature energy

from several different sources must be

used to meet the onsite loads. It is

assumed that the highest temperatures

available to the system are obtained

from burning fossil fuels or biomass,

fluids emerge from collectors at a lower

temperature, and fluids emerging from

high-temperature storage are at a still

lower temperature. (In most cases examined, it is assumed, however, that all

three provide identical temperatures

but an option for using different temperature is kept open. The efficiency of

the first engine must be adjusted to

reflect the different fluid temperatures.) The highest temperature fluids

are used in the engine whenever possible.

I I

A COMPUTER ANALYSIS

OF COGENERATION

A Fortran computer program was prepared for this analysis which performs the

optimization procedure just described. A

sample of the data, which the program requires to perform an evaluation of a cogeneration system, is illustrated in table 111-1

and a sample of the formatted output of the

program is illustrated in table II 1-2. A listing

of the package of programs is shown in appendix 1 I l-B. An operating manual explaining the use and operation of these programs

in greater detail is available as a separate

Volume.

CALCULATION OF

COLLECTOR PERFORMANCE

The techniques used to compute the thermal output of different kinds of collectors

were explained in the appendix to chapter

Vlll of volume I and the equations used to

compute the thermal and electrical output

of photovoltaic devices were discussed in

chapter X of volume 1. The following section

describes how the formulas developed in

volume I were used to evaluate the systems

analyzed.

Collector output is computed in three
Ch. III Calculation of Backup Requirements ● 5.?

Table Ill-1 .—Sample Input

TOT IO . JB

TITLE : PHOTOVOLTAIC COGENERATION--HIGH RISE, ALB (TEST SYSTEM)

SAVE HOURLY ELECTRICAL OUTPUT: NO

PRINT MONTHLY TOTALS OF SOLAR/DEMAND VARIABLES: YES

PRINT AVERAGE AND END OF MONTH VALUES OF STORAGE: YES

PRINT INPUT SUMMARY: YES

USE SEASONAL PARAMETERS: NO

FILE NUMBER FOR SYSTEM COEFFICIENTS: 90

LIST/CHANGE VARIABLES AND VALUES: NON

MAXIMUM PUMP/FAN LOAD--HEATING, COOLING (KW FAN/TOTAL OUTPUT): 59.24 59.24

HEAT LOSS FOR LT TANK OF LOW TEMP STORAGE (KWH/DEG CENT/HR): 0.001

AMBIENT TEMP. FOR LT STORAGE (DEG CENT): 25

FILE NUMBER FOR COLLECTOR COEFFICIENTS: 91

LIST/CHANGE VARIABLES AND VALUES: NON

FILES FOR ELECTRIC H/C COP’S: 43 44

INITIAL. VALUES OF LOW TEMP> HIGH TEMP, AND ELEC STORAGE (KWH): 5131/

subroutines:

COLL1, which is used for flat-plate collectors and two-axis tracking collectors (except

heliostats]

COLL2, which is used for one-axis tracking

collectors; and

COLL3, which is used for heliostats.

The three programs are very similar in basic

structure. As a result, only the COLL1 program is discussed in detail the discussion of

the other two subroutines concentrates

primarily on features that differ fro m

COLL1.

Each subroutine can be entered in four

different ways. These entry points are illustrated in figure III-5. The collector subroutine is called initially to read information

from external files and to convert this data

into a form that can be used in the computation. The subroutines obtain information in

two steps. First two files are read; one containing the solar declination for each day of

the year and one containing information

about the performance of the collector. A

sample file of collector performance characteristics required to operate the program

was shown in table III-2. After these files are

read, the performance characteristics can

be changed as necessary. The revised set of

performance characteristics can be saved in

a new file for later use if this is desired.

The program is then entered for each hour

of the year to compute the electrical and

thermal output of collectors given information about ambient air temperature, the

temperature of fluids entering the collector,

and (if a fixed output temperature is specified) the output temperature of the collector.

At the end of the yearly computation the

program is entered two more times to print a

description of the collector and to summarize the assumptions made about collector

performance.

The COLL1 Collector Subroutine

The COLL1 subroutine computes the output of either flat-plate collectors or two-axis

tracking collectors. It can be used to compute the output of collectors that provide

only thermal energy, of photovoltaic collectors that provide only electrical output, or

of photovoltaic cogeneration systems that

provide both thermal and electric output. A

listing of the program is given in appendi x

III-B.

Figure III-6 shows a flow diagram for the

section of the program which reads and converts the initial data (entry point 1 on figure

I I 1-5).

The first input read is a table of declina-
Table Ill-2.—Sample Output

DATE : 8/17/78

TIME: lb: 9:14

PHOTOVOLTAIC SYSTEM

ELECTRIC BACKUP

TWO-AXIS TRACKING SYSTEM

COMBINED THERMAL AND ELECTRIC COLLECTOR

CONSTANT OUTPUT TEMPERATURE

LOADS SET UP FOR HIGH RISE APARTMENT BUILDING

THE MISCELLANEOUS ELECTRIC LOADS AND THE HOT WATER LOADS

ARE NOT SMOOTHED

SYSTEM COEFFICIENTS:

REAL NUMBERS # VALUE DEFINITION

1

2

3

4

5

6

7

8

9

10

11

12

13

14

15

16

17

18

19

20

21

22

23

24

25

26

27

28

29

0 .

8.000E-01

1.000E+OO

1.000E+OO

o.

0.

0.

0.

0.

0.

:ABSORPTION A/C COP (DIM)

:ELECTRIC HOT WATER HEATER EFFICIENCY

:MULTIPLIER FOR ELECTRIC HEATING COP’S

:MULTIPLIER FOR ELECTRIC COOLING COP’S

:BOILER EFFICIENCY (.LE. 1.00)

:MAXIMUM TOPPING ENGINE OUTPUT (KU)

:EFFICIENCY OF ENGINE #1 (.LE. 1.00)

:EFFICIENCY OF ENGINE #2 (.LE. 1.00)

:ALPHA l--HIGH TEMP WASTE HEAT COEFF.

:ALPHA 2--Low TEMP WASTE HEAT COEFF. (1

.LE.

(DIM

(DIM

DIM)

(DIM)

o . :CAPACITY OF HIGH TEMPERATURE STORAGE (KWH)

5.380E+02 :LOW TEMP. OF HIGH TEMP. STORAGE (DEG CENT)

7.600E+02

1.000E+04

2.700E+01

6.600E+0l

o.

0.

1.000E-03

o.

1.200E+03

7.500E-01

1.000E+06

9.500E-01

8.305E+02

5.037E+02

0.

7.000E+O1

7.700E+01

COLLECTOR_ COEFFICIENTS:

REAL NUMBERS

7 VALUE DEFINITION

:HIGH TEMP. OF HIGH TEMP. STORAGE (DEG CENT)

:CAPACITY OF LOW TEMPERATURE STORAGE (KWH)

:LOW TEMP. OF LOW TEMP. STORAGE (DEG CENT)

:HIGH TEMP. OF LOW TEMP. STORAGE (DEG CENT)

:HEAT LOSS--HIGH TEMP. STORAGE (KWH/DEG CENT/HR)

:EFFICIENCY OF FOSSIL HOT WATER HEATER (.LE. 1.00)

:HEAT LOSS--LOW TEMP. STORAGE (KWH/DEG., CENT/HR)

:ENGINE BOILER EFFICIENCY (.LE. 1.00)

:CAPACITY OF EL ECTRIC S TORAGE (KWH )

:EFFICIENCY OF ELECTRIC STORAGE (.LE. 1.00)

:CAPACITY OF ELECTRIC POWER CONDITIONER (KU)

:EFFICIENCY OF POWER CONDITIONING (.LE. 1.00)

:MAXIMUM HEATING LOAD (KU)

:MAXIMUM COOLING LOAD (KU)

:FAN COEFFICIENT (KW FAN/KW OUTPUT)

:LOW TEMP. FOR OPEN WINDOWS--A/C CUTOFF (DEG F)

:HIGH TEMP. FOR OPEN WINDOWS--HT CUTOFF (DEG F)

1 5.000E+02

2 7.6OOE-01

3 2.500E+03

4 3.508E+01

5 1.066E+02

6 1.050E+02

7 3.508E+01

8 0.

,00) 9 5.000E+00

10 2.1OOE-O3

11 2.200E-01

12 9.500E-01

13 1.000E.+00

14 1.500E-O.2

15 1.000E+OO

16 1.000E+OO

17 9.800E-01

18 l.000E+0l

19 1.000E.+00

20 1.000E+00

INTEGERs

# VALUE DEFINITION

1

2

3

4

5

6

7

8

1 :HIGH TEMPERATURE STORAGE (MIX(2), NO MIX(l))

1 :LOW TEMPERATuRE STORAGE (MIX(2), NO MIX(l))

1 :BACKUP (FOSSIL FUEL(0), ELECTRIC(I), BOTH(3))

3 :SOLAR COLLECTOR (NONE(0),FP(1),1D(2),2D(3),HEL(4)

1 :AIR CONDITIONING ON(1) OR OFF(2)

o :REGULAR LOADS(0) OR SMOOTHED LOADS(1)

1 :SINGLE FAMILY(O), HIGH RISE(l), SHOPPING CENTER(2

o :BUY OFFPEAK ELEcTRICITY (NO(0), YES(l))

:CONCENTRATION RATIO (DIM)

:OPTICAL EFFICIENCY OR TRANSMISS. (.LE. 1.00)

:COLLECTOR AREA (M**2)

:LATITUDE (DEG)

:LONGITUDE (DEG)

:STANDARD LONGITUDE (DEG)

:COLLECTOR TILT ABOVE HORIZONTAL (DEG)

:COLLECTOR ANGLE WRT SOUTH (DEG)

:COLLECTOR HEAT REMOVAL FACTOR (KW/(M**2*C))

:CELL TEMP COEFF (1/DEG CENT)

:CELL EFFIC @ 28C (.LE. 1.00)

:CELL ABSORPTIVITY (.LE. 1.00)

:FRAC OF RECEIVER COVERED WITH CELLS (.LE. 1.00)

:THERMAL LOSS COEFF (KW/M**2*C)

:NUMBER OF GLASS COVERS (DIM)

:COLLECTOR HEAT REMOVAL FACTOR (.LE. 1.00)

:ABSORB OF THERMAL-ONLY SURFACES (.LE. 1.00)

:FLOW RATE (CM**3/SEC*M**2)

:FLUID DENSITY (GM/CM**3)

:FLUID SPEC. HEAT (CA L/G M*C)

INTEGERS

I t VALUE —

DEFINITION

:OUTPUT--ELEC( 1) , ELEC & THERMAL(2), THERMAL(3)

2 2 :CONST FLOW RATE(1) , CONST OUTPUT TEMP(2)

STORAGE HEAT LOSS COEFFICIENTS

HEAT LOSS AMB. TEMP

(KWH/DEG CENT/HR) (DEG. CENT)

UT STORAGE O. -- 0. 25.0

LT STORAGE 1.000E-03 -- 1.000E-03 25.0

NOTE: FIRST HEAT LoSS NUMBER IS FOR HT TANK OF THE PARTICULAR

STORAGE; SECOND IS FOR LT TANK OF THE SAME STORAGE.

ELECTRIC H/C cOP’S (KWH/KWH)

TEMP HEAT TEMP COOL

10.0 1.00 75.0 2.50

20.0 1.00 80.O 2.35

30.0 1.00 90.0 2.07

40.0 1.00 100.0 1.86

50.0 1.00 110.0 1.67

60.O 1.00 120.0 1.52

70.0 1.00 -- --
Table III-2. —Sample Output (Continued) (Cont. )

(IF

Month ELECT R IC

1 1 .53.E - 01

2 1.955 E - 01
56 ● Solar Technology to Today’s Energy Needs

Figure III-5. —Entries to Collector Subroutines

COLL1, COLL2, and COLL3

entry point # 1

Read input files. modify

collector coefficients,

and perform initial

computations

I Compute collector I

I

output

I

I

tion angles for each day of the year (line

2014). The direct normal radiation (RADDN)

and the hourly total horizontal radiation

(RADTH) for the first hour in the year are

read from file 25, which contains RADDN

and RADTH for each hour of the year in the

region being studied. (This file also contains

temperature and wind velocity data, which

are read into the RADDN array but are then

overlaid. ) The file containing the collector

coefficients is then specified from the terminal or from a stored file. A negative number will set all coefficients to zero. Lines

2020 to 2025 allow the operator to list the

collector coefficients read from the file, and

to make changes in the assumed collector

performance characteristics if this is required.

Changes to the collector coefficients are

input using lines 2057 to 2066. The COMMON statement (lines 2005 to 2008) places

the variables named in the COMMON statement into the computer’s memory space in

the order given. The EQUIVALENCE statement [line 201 O) then creates arrays SCEL

and ISCEL, which contain the collector coefFigure hi-6.-Flow Diagram for Entry Point #1 to

COLL1, COLL2, and COLL3

ficient variables in exactly the order given in

the COMMON statement. Lines 2057 to 2061

allow the values of any real coefficient to be

changed by specifying the coefficient

number (as given in the left column of lines

2033 to 2052) and the new value. Input of a

negative value will make the program move

to the integer variables. The intege r

variables of lines 2055 to 2056 are changed

using lines 2062 to 2066. The modified coefficient files can be stored (lines 2067 to 2070)

by specifying a positive file number. Zero or

a negative number causes the modified

values to be retained until execution of the

main program terminates.

The program then calculates several

quantities for use in the hourly computa-
Ch. Ill Calculation of Backup Requirements ● 5 7

tions of collector output. The latitude angle

(LAT), collector tile angle (TILT), and the collector azimuth angle (AZ), which were input

in degrees, are converted to radians for use

in the Fortran program.

The collector absorber area AREACR is

calculated by dividing the collector area by

the concentration ratio. The quantit y

XMASSF = (fluid flow volume) x (specific

heat) x (density) is computed.

ALPHAV is the effective thermal absorptivity computed from the absorptivity of the

photovoltaic celIs, (ELECAB), the absorptivity of the portion of the collector not

covered with celIs, (ALPHA), and the fraction of the collector absorber covered with

cells, (FC). The program then calculates the

length of each day of the year, (DAYLEN (l)),

and the correction factor used to convert

local time to solar time, (SONOON (1)). EQ(J)

is the equation of time discussed in chapter

Vlll of volume 1. SONOON (1) converts the

hour number to solar time using EQ(J), a

constant shifting the time to the middle of

the hour and accounting for the fact that

hour #1 in each day in the weather arrays

(RADDN and RADTH) corresponds to the

hour from midnight to 1 a.m. and a term that

accounts for locations at longitudes other

than standard time zone longitudes.

The hourly computation of collector output begins with Iine 2101. The pattern of this

computation is shown in figure I I 1-7. First

RADTH and RADDN are checked to see if

the Sun is shining. If both are small, the program sets the collector output(s) to zero,

and the computation is complete for the

hour. If there is sunlight available the program must compute the hour of the day (J)

from the hour of the year (K). It does this by

first computing the day number (1). The program next determines whether the hour being examined is less than half an hour after

sunrise or before sundown; if this is the case,

the program sets the output to zero and

returns. (These hours are excluded from the

calculation since the algorithm used to compute diffuse radiation can give anomalously

high values under these conditions and the

amount of energy available during these

hours is negligibly small on an annual basis.)

RI SANG (line 2110) is the solar hour angle at

sunrise.

If it is determined that collector output

should be calculated for hour K, the program must first determine what kind of colIector is used. It is assumed that the collector is a flat-plate device if a concentration

ratio (C RATIO) less than 1.5 is specified;

otherwise, the collector is assumed to be a

two-axis tracking collector that can collect

only the direct radiation. If the collector is a

concentrator, the program either branches

to 222 to compute thermal output or goes to

224 to compute electric output if the collector provides only photovoltaic electric output (ISYS = 1).

The total useful sunlight striking a square

meter of collector absorber (RADTOT) is

calculated for concentrators at normal incidence to the Sun. For fiat-plate collectors,

the program calculates the cosine of the incident angle (COSINC) on Iines 2115 to 2127.

If COSTHE is negative, representing an instance where the Sun is behind the Collector,

the program Sets the output(s) to zero and

exits. The diffuse radiation (RADDIF-lines

2128, 2129) striking the tilted collector is

calculated as given in equations VII l-A-l 4

and VII l-A-l 5 of volume 1, and is set to zero

if it is calculated to be negative. If the collector is a passively cooled photovoltaic array (ISYS = 1), the program skips to line

2149 to calculate the electric output. Calculation of the total radiation striking the collector absorber (RADTOT) depends on

whether there are one or two cover s

(COVERN less than or greater than 1.5). The

exponents of COSINC (lines 2132, 21 34) are

greater than one to represent the angular

dependence of the cover transmission on

the incident angle and the factors ‘0.89 and

0.80 represent this angular dependence integrated over a hemisphere for the diffuse

radiation as given by equations VII l-A-l 7

and VI I l-A-l 8 of volume 1.

The total collector output is computed in

lines 2135 to 2152. The output of collectors
58 • Solar Technology to Today’s Energy Needs

Figure III-7 .–FIow Diagram for Computing Hourly Collector Output Using COLL1

Entry point #2

Is the sun No

shining?

Is it more than

1⁄2 hour after sunrise No

No I

Does this collector

. . I

Return
Ch. III Calculation of Backup Requirements • 59

that provide only thermal output is computed with the fractional cell coverage ratio

(FC) set to zero in the expressions used for

collectors that also provide electric output.

The useful thermal output QA of a unit

area of collector absorber operated at constant output temperature can be computed

from the heat balance equation:

al = F, q I + Q,f + U , (T - Ta) (32)

where a is the average absorptivity for the

collector (ALPHAV), I is the level of insolation on the absorber (RADTOT), q is the

photovoltaic cell efficiency, F C is the fraction of the absorber area covered with cells

(FC), UL is the thermal loss coefficient

(U LOSS), T is the average temperature of the

collector absorber and photovoltaic cells

(TCELL), and Ta is the ambient air temperature (TAIR).

The value of I is given by the following

relations for flat-plates or concentrating systems:

I = ID COS8,7(() + Id Td (f tat plates)

I = IDC,qO (concentrating systems)

where:

ID = direct norma l sola r intensit y

(kW/m

2

),

6, = angle between the Sun and the

normal to the CoIIector,

7(01) = transmissivity of celI covers for

direct radiation (at angle 0,),

ld = intensity of diffuse solar radiation

(kW/ m

2

,

7d = transmissivity of celI covers for

diffuse radiation (~(?l) integrated

over all incident angles),

C r= geometric concentration ratio of

concentrator optics, and

q, = optica I efficiency of t h e

concentrator.

The celI efficiency q is given by:

~ = ~(28 0)(1 – 6 [T (33) – 281)

where q (280, is the cell efficiency at 28“C

(CELLEF) and ß is the cell temperature coefficient (BETA).

The average absorber temperatur e

(TCELL) is:

~ = Tf + QA/ ke (34)

where Tf is the average collector fluid temperature (TTEMP) and ke is the thermal conductivity (XKE) between the absorber surface and the fIuid.

Combining equations (32) through (34)

and multiplying by the total absorber area,

the thermal output QSR (line 2142) is given

by:

QSR =AAFR

I[a-FCq(28XI -flTf28])]-UL (Tf -Ta)

(35)

1{FC IV (28)@ - UL)/ke

where AA is the absorber area (AR EACR).

Note that the program sets FR = 1 (line 2096)

for this case.

For the case of constant flow rate, QSR is

developed somewhat differently. The output QA can now be written (see discussion of

equation VII l-A-27 of volume l).

Q A 

= F,[~l - TI F,l - UL

( T1 - Ta ) (36)

where Fr is the collector heat removal factor

and T, is the temperature of the fluid at the

CoIIector inlet. The celI efficiency can be expressed as:

(37) ~ = ~(28) [1 - ß~(T, + AT12 + QAk e 

- 28)]

where the fluid temperature rise across the

colIector is:

A,= “ (38)

QCPf

where Q is the fluid density, CP is the fluid

specific heat, and f is the fluid flow rate.

XMASSF (lines 2086, 2140, 2146 corresponds

to the denominator of equation (38).

CRATIO and the constant are required to

convert the inputs provided to the units

kW/oCM2 [absorber).

The electric output for those collectors

that provide both thermal and electric output QE (ESR) is (line 2147).

Q E = A AF( Iq (39)
60 ● Solar Technology to Today’s Energy Needs

The electric output of passively cooled

CoIectors can also be computed from equation (39). However, the cell temperature T is:

~ = Ta +

al - FCVI (40)

ke

where ke is now the overall thermal conductivity between the cells and ambient air.

Combining (33), (39), and (40), the electric

output (lines 2151, 21 52) is:

Q E =

A~FCl~28) [1 ß(Ta +(xI/k, –28)] (41)

1 – FClB~(28)/k,

The output(s) are passed back to the main

program after ensuring that they are nonnegative (lines 2153 to 21 54). The exit at Iine

2158 is used if the output computation is

skipped for lack of sunlight.

The “output statements” (lines 2162 to

2178) are simply a brief description of the

type of collector that has been modeled.

The monthly and annual totals of collector

output are given in the main program. The

“output summary” provides a printout of

the collector coefficients that were used in

making the run, if requested in the operating

instructions for the main program. The three

angles shown (lines 2184 to 2186) are converted back to degrees before writing the

output summary.

The COLL2 Collector Subroutine

This subroutine computes the output of

single axis-tracking collectors with either a

north-south polar axis orientation or with a

horizontal east-west collector axis. The collectors may provide thermal output, electricity from photovoltaic cells, or both thermal and electric output. This subroutine differs from COLL1 principally in the hourly

computations performed. Computation of

the incident angle is simpler, computation

of shading by adjacent collectors is performed, and a slightly more elaborate computation of thermal losses is performed (to

increase accuracy if the CoIIector is operated over a wide range of output temperatures). A listing of the program appears in

appendix I I I-B and a flow diagram for the

entry which calculates collector output is

shown in figure I I 1-8.

Figure III-8.—Flow Diagram for Computing Hourly

Collector Output Using COLL2

Is the sun

shining? No

Yes

t
CH. III Calculation of Backup Requirements • 61

The first part of the program (lines 2000 to

2025) again initializes and contains the first

two input prompts. A few variable names

differ from COLL1.

The second part of the program contains

the format for reading and revising values of

colIector coefficients.

The section starting with line 2082 differs

from the COLL1 program because COLL2

does not require a specified collector tilt

and azimuth angle. XMINV is simply 1/(2 •

XMASSF) with XMASSF as defined in COLL1.

RRR is the fraction of the collecto r

absorber-pipe length that is covered with

photovoltaic cells and is zero for collectors

that provide only thermal output.

Computation of incident angles is simpler

than in COLL1. Line 2113 computes the

cosine of the Sun’s incident angle for a

north-south polar axis collector using equation VII l-A-8. If the collector has an eastwest axis, (IEW =1) COSINC is recomputed

in Iine 2118 using equation VII l-A-9.

Collector Shading

Two types of shading can occur in any array of the troughs or single-axis tracking collectors treated in COLL2: 1 ) shading caused

by a row of collectors located to the south

of another row of polar-axis collectors; and

2) shading by the adjacent collector during

early morning and Iate afternoon hours (e. g.,

the collector to the north or south of an

east-west axis collector). In theory both of

these factors can be eliminated by increasing the spacing between collectors, but in

most cases this is not a practical solution

because of the great increase in land use

that it requires.

For polar tracking arrays, shading of

northerly rows by southern rows of collectors is minirna[ if the space between the

rows is equal to the row width and spacing

within a row is reasonable. For east-west

tracking arrays, the trough axes are horizontal, and only shading by adjacent collectors

is significant. The program therefore

assumes that row shading can be eliminated

by proper spacing.

The geometry of adjacent-collector

shading is illustrated in figure I I 1-9. Assuming that the collector aperture width is W

(APWID) and the collector spacing is D

(COSPAC), it can be shown that for long collectors the unshaded fraction of the collector is:

Figure Ill-9.—Sectional View of Parabolic Trough

Collectors for Shading Computation

D

The end losses of one-axis collectors are

given by equation VII I-A-20 in volume 1. The

fraction of light which can reach the absorber is:

where f = F/D is the f-number of the system

and Lt is the collector length. The combined

effect of both types of shading and end

losses is computed in the line 2132. Note
62 . Solar Technology to Today’s Energy Needs

that Iine 2125 tests for a

Sun is behind a polar

sends the program to a

if this occurs.

condition where the

axis collector and

RETURN statement

The section beginning with line 2136 completes the computation of the sunlight absorbed by the collector and begins the

calculation of thermal output. TRANSM is

the fraction of Iight transmitted through the

absorber cover assuming that the cover is

approximately perpendicular to the Iight ray

when the collector is pointing directly at the

Sun. It is assumed that there is a single cover

and TRANS is the transmissivity of the cover

at normal incidence. FCIONO is non-zero

only if the collector contains photovoltaic

cells and if the entire length of the cells is illuminated. It is zero when some cells are

shaded by end effects since the electrical

output in this case would be very small.

When FCIONO is non-zero, it is the product

of the cell efficiency (CELLEF), the fraction

FC of the absorber width covered with cells,

the light intensity incident on the cells, and

the ratio of cell length to the collector

length (C EL L/CO LEN).

ALPHIO is the average energy absorbed

by a unit area (M’) of the absorber and corresponds to the product CYI discussed for

COLL1. ALPHIO is given by (lines 2141 to

21 50):

where:

C r= ratio of collector aperture t o

absorber area (concentration ratio,

(C RATIO))

L t = total length of collector absorber

(COLEN)

L C = absorber length covered wit h

photovoltaic cells (CELLL)

(COSINC)

absorptivity of absorber surface not

covered with cells (ALPHA)

absorptivity of cells (ELECAB)

F C = fraction of area Lc x (width )

actualIy covered with celIs.

It is assumed that a row of photovoltaic

celIs of length LC are centered in the I i near

absorber whose length is Lt

. It can be seen

that (r,

entire cell length, one end section and part

of the other end section receiving sunlight.

– 0.5)Lt <-L C/2 corresponds to less than

one end section being illuminated, and

section and part of the cell length being in

the refIected sunlight.

If the collector provides only electric output, (ISYS = 1), the computation of thermal

output is skipped. otherwise, the a p -

propriate collector temperature TTEMP is

computed. The calculation of TTEM P

depends on whether the collector operates

with fixed flu id flow rate (1 FLOW = 1 ) or with

fixed output temperature (I FLOW =2).

The thermal output of collector s

operated with fixed output temperature is

computed in lines 2159 to 2163. The computation of QL2, which is proportional to

the thermal losses (equal to, if there are no

solar cells), utilizes two thermal loss coefficients. The efficiency of a collector is not a

linear function of temperature; a typical efficiency function is illustrated in figure

I I I-10. Particular care must be taken to account for the nonlinearity if the collectors

are operated over a wide ‘range of temperatures. The algorithm used by the program

approximates the efficiency curve with two

straight Iine segments as shown in the figure.

The effective incremental thermal losses in

the two temperature ranges are computed

as follows:

(45)

T, -TO

u 2 =
Ch. III Calculation of Backup Requirements ● 6 3

If the difference between the average collector temperature and the air temperature

( Tf - Ta is greater than the difference T1 - To

,

then both U1 and U2 are used to compute

the thermal output. Using the notation

which has been developed in the discussions

of COLL1 and COLL2, the thermal output is

Figure III-10. —Typical Collector Efficiency Curve

This equation can be derived in a fashion

similar to that used in the discussion of

used and the thermal loss portion of the

equation reduces to U1

( Tf – Ta). If one

wishes to run the program using a single

thermal loss coefficient, set U1 = U2 and set

T O and T1 to arbitrary values.

The thermal output of collector s

operated at a fixed flow rate is calculated in

lines 2168 to 2173. For this case, the thermal

output is given by:

if Ti – Ta T 1 – TO

, As for fixed outpu t

temperature, the therma l loss portio n

program can also be operated with U1 = U2

as above. This algorithm implicitly assumes

that the flow rate is great enough that the

temperature rise across the collector is not

so large that the loss calcuIation wiII be significantly affected if Ti – Ta is nearly a s

large as T1 – To

.

The electric output of coIIectors that also

provide thermal output is computed on line

2175 as:

- 28)] (48)

keAc

The electric output of passively cooled

Colectors is calcuIated on Iine 2178 as:

(49)

c ,

(47)

Collector Subroutine COLL3

This subroutine computes the thermal

output of a heliostat field. I t does not perform a detailed computation of the shading,

blocking, and incidence angles for each

heliostat in the field, but rather utilizes output curves computed for a particular field

by the University of Houston and modifies

these results to account for different latitudes. Since it computes only thermal output and uses a rather simple approximation

for the shading and incident angle factors,

this subroutine is both shorter and simpler

than the other two collector subroutines.

The program is listed in appendix III-B and

the flow diagram for the output computation of COLL3 is shown in figure I I 1-11.

The first part of the subroutine again performs initializations and reads input data.
64 • Solar Technology to Today’s Energy Needs

Figure III-11. —Flow Diagram for Computing Hourly

Output of a Hellostat Field

Lines 2013 to 2015 contain data for use in

the computation of the absorbed sunlight.

Since this subroutine is considerably

simpler, it requires only about a third of the

input coefficients (lines 2035 to 2042) of the

other two subroutines. The solar time and

other quantities used in the hourly computation are calculated in lines 2055 to 2065.

This subroutine performs checks to see if

the Sun is shining and if it is more than half

an hour after sunrise or before sunset just as

the other subroutines. The major difference

is the manner in which the incident sunlight

is computed. N, TD, TB, and TC are all used

to compute the factor GAMCOS, which represents the average incident cosine factor

and shading factor for the entire heliostat

field. GAMCOS is calculated using line

segments to determine the maximum input

available at each time of the day as discussed in chapter VII I-A and shown in figure

VI II-A-4 of volume 1. Once GAMCOS is

known, the thermal output QSR is simply

the absorbed radiation minus the thermal

losses:

where Tfo is the CoIIector output tempera -

ture .

Note that this subroutine uses the collector area AREAC instead of the absorber area

AREACR in the computation, The thermal

losses are based on the output temperature

TFOUT since it is assumed that these systems will operate at fixed output temperature and the thermal loss coefficient ULOSS

was specified for a particular temperature.

Since radiation is the major thermal loss in

many such systems, ULOSS is a strong function of the output temperature.
Appendix III-A

Proof of Valve Opening Sequence

For a given set of valve settings in the

diagram illustrated in figure 2, the amount

of electricity (E) and the amount of thermal

energy (Q) provided by the system can be

written in terms of the amount of high-temperature energy entering the system (QH

) a s

follows:

(A-1)

(A-2)

The valve settings depend on the ratio of Q

to E, the energy required to meet the loads.

Clearly if Q =0 the optimum valve settings

are Y= I and ß=1. This situation also holds

as long as the minimum amount of thermal

energy exhausted in producing the needed

electrical output exceeds Q.

Therefore,

(A-3)

Then ß = 1

must be less than one. At the point where

held constant and Q is increased by an intal change in QH required to meet a load E

tion (A-1 ) as follows:

(A-4)

(A-5)

reduces to:

(A-6)

situation which will hold in all practical

cases. ) Because energy is conserved we

know that

(A-7)

or equivalently that

(A-8)

equation (A-5), QH is minimized by changing

of one. Therefore:

ß 1

=

‘Y (A-9) =

fore, if:

(A-1O)

=

ß

E

=

This proves the sequence stated in the text

VIZ, For small values of QO

/EO both ß and ~

are one. As the ratio increases to a point

where demands cannot be met with this

valve setting without discarding electrical

energy, the valve characterized by ~ should

be adjusted first, keeping ß=1. The quantity

ß should only be reduced from 1 when the

opt i mum setting for T =0.

65
TOTIO.PB-PNC/UGFO02 08/17/78 14:41:56

1.

2.

3.

4.

5.

6.

7.

8.

9.

10.

11.

12.

13.

14.

15.

16.

17.

18.

19.

20.

21.

22.

23.

24.

25.

26.

27.

28.

29.

30.

31.

32.

33.

34.

35.

36.

37.

38.

39.

40.

41.

42.

43.

44.

45.

46.

47.

48.

49.

50.

51.

52.

53.

54.

55.

1000.

1001.

1002.

1003.

1004.

% PROGRAM NAME: TOTIO.JB

% JOHN C. BELL

% ENERGY PROGRAM

% OFFICE OF TECHNOLOGY ASSESSMENT

% COMPILED

z DATE: l/12/78

z TIME: 13: 6: 1

% PROGRAM TOTIO.JB FOR RUNNING SOLAR AND NON-SOLAR SYSTEMS

% FILE HANDLING REQUIREMENTS:

% 12—FILE NUMBER FOR GENERAL INPUT IN TOTIO.JB, THE LOAD

% SUBROUTINES, AND THE COLLECTOR SUBROUTINES. NORMALLY

% THIS IS EQUATED TO IN$ FOR TERMINAL INPUT.

% 13--FILE NUMBER FOR GENERAL OUTPUT IN TOTIO.JB, THE LOAD

% SUBROUTINES, AND THE COLLECTOR SUBROUTINES. NORMALLY

% THIS IS EQUATED TO OUT$ FOR TERMINAL OUTPUT.

% 20--FILE HOLDING HEATING/COOLING LOADS, PROCESS LOADS, AND

% MISCELLANEOUS ELECTRIC LOADS

% 25—FILE HOLDING WEATHER AND INSOLATION DATA

% 50-–FILE FOR OUTPUTTING HOURLY ELECTRIC BACKUP/SELL DATA

% (REQUIRED ONLY FOR UTILITY IMPACT ANALYSIS AND DEBUGGING)

% XX–-FILES HOLDING SYSTEM COEFFICIENTS, CELL COEFFICIENTS, AND

% ELECTRIC HEATING/COOLING COP’S ARE PROMPTED FOR IN THE

% MAIN PROGRAM

%

%

% TOTIO.JB MUST BE LINKED TO THE FOLLOWING:

z UPDATE.JB--ALWAYS

.% ONE LOAD SUBROUTINE

z LOADS.JB--SINGLE FAMILY HOUSE, INSULATED SINGLE FAMILY

% HOUSE, TOWNHOUSE, HIGH OR LOW RISE APARTMENT

% LOADSC. JB--SHOPPING CENTER

. % ONE COLLECTOR SUBROUTINE

% COLL1.JB--FLJT PLATE COLLECTORS AND TWO-DIMENSIONAL

% TRACKING COLLECTORS

% coLL?.JB --oNEDIMENsIoNAL TRACKING COLLECTORS

% COLL3.JB-–HELIOSTATS

% ONE SYSTEM SUBROUTINE

% HFSYS—HEAT ENGINES WITH FOSSIL BACKUP

% HESYS--HEAT ENGINES WITH ELECTRIC BACKUP

% PVSYS--ALL PHOTOVOLTAIC SYSTEMS

% HWSYS--SOLAR HOT WATER SYSTEMS

%

%

% MISCELLANEOUS INFORMATION

z --ALL LOADS AND MAXIMUM OUTPUTS ARE IN KILOWATT-HOURS AND

% KILOWATTS

% --QSH HOLDS THE SPACE CONDITIONING LOAD

% --NEGATIVE MEANS A HEATING LOAD

% --POSITIVE MEANS A COOLING LOAD

% --HWLOAD HOLDS THE PROCESS (HOT WATER) LOAD

% --E HOLDS THE MISCELLANEOUS ELECTRIC LOAD PLUS THE FAN AND

% PUMP LOAD

z --ELLOAD HOLDS THE MISCELLANEOUS ELECTRIC LOAD

%

DIMENSION E(8760),HWLOAD( 168) ,M(13),IMTH(12)

DIMENSION COEF(30),ICOEF(8) ,TITLE(15)

DIMENSION FUELMO(12),TOTEM( 12) ,TOTSM( 12),TALTE(12)

DIMENSION ESRM(12),QSRM( 12),QCCM( 14),QCHM( 14),EEEM(12) ,QPM(12), %

TEMPM(12)

TOT10.PB-PNC/UGF002 08/17/78 14:41:56

1005.

1006.

1007.

1008.

1009.

1010.

1o11.

1012.

1013.

1014.

1015.

1016.

1017.

1018.

1019.

1020.

1021.

1022.

1023.

1024.

1025.

1026.

1027.

1028.

1029.

1030.

1031.

1032.

1033.

1034.

1035.

1036.

1037.

1038.

1039.

1040.

1041.

1042.

1043.

1044.

1045.

1046.

1047.

1048.

1049.

1050.

1051.

1052.

1053.

1054.

1055.

1056.

1057.

1058.

1059.

1060.

1061.

1062.

1063.

1064.

DIMENSION CPH(2,25),CPC(2, 25)

DIMENSION ESE(12),LSE(12),HSE( 12) ,ESM(12),LSM(12) ,HSM(12),0LDST(3)

IMPLICIT REAL(L)

COMMON/AXXX/COPA, EHWEFF, HCOPM,CCOPM,EFFB,ENGMAX, EFF1,EFF2,ALPHA1, %

ALPHA2,HTQSTM,LTHTS,HTHTS, LTQSTM,LTLTS,HTLTS,HLHTH, %

FHWEFF,HLLTH, EFFBE,ESTORM, EFFBAT, PCSIZ, EFFPC,HEATMX, %

COOLMX,FAN,TL,TH,KXX,NHTQ,NLTQ, IGRID, ISOIAR,IA,ISMTH, %

IHR,IOFFPK

EQUIVALENCE (COEF(l),COPA) ,(ICOEF(l),NHTQ)

COMMON/CXXX/COPAA,COPEE ,EBM, EBEM,EEE,EFFEX,TENCM, BENGM,ENGM, %

ESR, ESTOR,EEFF,FFHW, FHET, FUEL,HTSSTM,HTQ,HTQI,HT@ , %

HTQSO, HTQSTO,LTQI,LTQO ,LTQSO,LTQSTO,QA, QC,QC I,QC2, %

QC2Z,QE,QP,QS,QSR,RESID 9, SHET,STHET,TOTTEO,TOTBEO, %

TOTEO,HLHTL,HLLTL,EFFLOT, EFFST,IPRINT

COMMON/DXXX/BOLMAX,CPC ,CPH,EEEM,EHM, EKMAX,EKMIN, ESE,ESI,ESIM, %

ESM,ESO,ESOM, ESRM,ESTMAX, ESTMIN, ESTORI,FUELMO, %

HRRUN, HSE,HSM,HTMAX, HTMIN,HTQIM,HTQOM, HTQSTI , %

IEC,IEH, IEOMST,IHRAV, IHRCT, IOUTS, J1O,J2O,J3O,LSE, LSM, %

LTMAX,LTMIN,LTQIM, LTQOM, LTQSTI,AMESR,AMQSR,QCCM, QCHM, %

QC1W,QC1X,QC1Y,QC2W,QC2X, QC2Y,QPM,QSRM,TALTE,TBAT, %

TEEE,TEMPM,TESR,THTQ,TLTQ,TOTE,TOTEM,TOTS,TOTSM, %

TQP,TQSR,TTEMP

COMMON/EXXX/TAIRF

COMMON/XDATA/E,HWLOAD

DATA M/1,745,1417,2161,2881 ,3625,4345,5089, 5833,6553,7297,8017,8761 /

DATA ITBOUT,HTSSTM/1, 1.0E+30/ @HTSSTM IS TEMPORARY HT STORAGE

READ(12, 98,PROMPT=’TITLE: ‘) TITLE

98 FORMAT(15A4)

READ(12, 99,PROMPT=’SAVE HOURLY ELECTRICAL OUTPUT: ‘) ITST

IF (ITST.NE.-YES’) GO TO 9081

IHROUT=l

READ(12, 99,PROMPT=’PRINT OUTPUT TABLES: ‘) ITST

IF (ITST.EQ.’NO’) ITBOUT=O

IF (ITBOUT.EQ.0) GO TO 4113

9081 READ(12, 99,PROMPT =%

‘PRINT MONTHLY TOTALS OF SOLAR/DEMAND VARIABLES: ‘) ITST

IF (ITST.EQ.’YES’) IHRAV=l

READ(12,99,PROMPT= %

‘PRINT AVERAGE ANE END OF MONTH VALUES OF STORAGE: ‘) ITST

IF (ITST.EQ.’YES’) IEOMST=1

READ(12,99,PROMPT=’PRINT INPUT SUMMARY: ‘) ITST

IF (ITST.EQ. ’YES’) IOUTS=l

4113 READ(12, 99,PROMPT=’USE SEASONAL PARAMETERS: ‘) ITST

IF (ITST.NE.’YES-) GO TO 1112

READ(12, *,PROMPT=’MONTHS TO INPUT CHANGES: ‘) IMTH

1112 READ(12,*,PROMPT-’FILE NUMBER FOR SYSTEM COEFFICIENTS: ‘) IF

IF (IF.LE.0) GO TO 1066

REWIND IF

READ(IF) COEF,ICOEF

1066 READ(12, 99,PROMPT=’LIST/CHANGE VARIABLES AND VALUES: ‘) ITST

99 FORMAT(A4)

IF (ITST.EQ.’YES’) GO TO 1081

IF (ITST.EQ.’NO’) GO TO 1082

IF (ITST.EQ. ’NON’) GO TO 1080

GO TO 1066

1081 WRITE(13,909) (COEF(I),I-1,29)

909 FORMAT(’ REAL NUMBERS—’/ %

‘ #’,4X,’VALUE’,4X,’DEFINITION’ /%

,

1 ’ ,IPEIO. 3,’ :ABSORPTION A/C COP (DIM)’/%

,

2’, IPEI0.3, ’ :ELECTRIC HOT WATER HEATER EFFICIENCY (.LE.l.00)’/%

3
TOTI0.PB-PNC/UGFO02 08/17/78 14:41:56

1065.

1066.

1067.

1068.

1069.

1070.

1071.

1072.

1073.

1074.

1075.

1076.

1077.

1078.

1079.

1080.

1081.

1082.

1083.

1084.

1085.

1086.

1087.

1088.

1089.

1090.

1091.

1092.

1093.

1094.

1095.

1096.

1097.

1098.

1099.

1100.

1101.

1102.

1103.

1104.

1105.

1106.

1107.

1108.

1109.

1110.

1111.

1112.

1113.

1114.

1115.

1116.

1117.

1118.

1119.

1120.

A121.

1122.

1123.

1124.

3 ’ ,IRE10. 3,’ :MULTIPLIER FOR ELECTRIC HEATING COP ‘“s (DIM)’/%

,

4 ’ ,IPE10. 3,’ :MlLTLTIPLIER FOR ELECTRIC COOLING COP “s (DIM)’/%

,

5 ’ ,1FE10.3, ’ :BOILER EFFICIENCY (.LE.l.00)’/%

,

6 ’ ,lPE10. 3,’ :MAXIMUM ToPPING ENGINE OUTPUT (KW)’/%

,

7 ’ ,1PE10.3, ’ :EFFICIENCY OF ENGINE #1 (.LE.l.00)’/Z

,

8 ’ ,lPE10. 3,’ :EFFICIENCY OF ENGINE #2 (.LE.l.00)’/%

,

9 ’ ,lPE10. 3,’ :ALPHA 1--HIGH TEMP WASTE HEAT COEFF. (DIM)’/%

‘ 10 ‘ ,lPE10. 3,’ :ALPHA 2--LOW TEMP WASTE HEAT COEFF. (DIM)’/%

’11 ’ ,1PE10. 3,’ :CAPACITY OF HIGH TEMPERATURE STORAGE (KWH)’/%

‘ 12 ’ ,lPE10. 3,’ :Low TEMP. OF HIGH TEMP. STORAGE (DEG CENT)’/%

‘13 ’ ,1PE10.3,’ :HIGH TEMP. OF HIGH TEMP. STORAGE (DEG CENT)’/%

‘ 14 ‘ ,lPE10. 3,’ :CAPACITY OF LOW TEMPERATURE STORAGE (KWH)’/%

‘ 15 ‘ ,1PE10.3,’ :LOW TEMP. OF LOW TEMP. STORAGE (DEG CENT)’/%

‘ 16 ‘ ,1PE10.3,’ :HIGH TEMP. OF LOW TEMP. STORAGE (DEG CENT)’/%

’17 ’ ,1PE10.3, ’ :HEAT LOSS--HIGH TEMP. STORAGE (KWH/DEG CENT/HR)’/%

‘ 18 ‘ ,lPE10. 3,’ :EFFICIENCY OF FOSSIL HOT WATER HEATER (.LE.l.00)’/%

‘ 19 ‘ ,lPE10.3,’ :HEAT LOSS--LOW TEMP. STORAGE (KWH/DEG CENT/HR) ’/%

‘ 20 ‘, 1PE10.3,’ :ENGINE BOILER EFFICIENCY (.LE.l.00)’/%

‘ 21 ‘, lPE10.3,’ :CAPACITY OF ELECTRIC STORAGE (’KWH)’/%

‘ 22 ‘ ,lPE10.3,’ :EFFICIENCY OF ELECTRIC STORAGE (-LE.l.00)’/%

‘ 23 ‘, 1PE10.3,’ :CAPACITY OF ELECTRIC POWER CONDITIONER (l(W)’/%

‘ 24 “ ,lPE10.3,’ :EFFICENCY OF POWER CONDITIONING (.LE.l-00)’/Z

, 25 ', 1PE10.3,’ :MAXIMUM HEATING LOAD (KW)’/%

‘ 26 ‘ ,lPEl0.3,’ :MAXIMUM COOLING LOAD (KW)’/%

‘ ,27 ', IPEl0.3,’ :FAN COEFFICIENT (KW FAN/KW OUTPUT)’/%

‘ 28 ‘, 1PEl0.3,’ :LOW TEMP. FOR OPEN WINDOWs--A/C CUTOFF (DEG F)’/%

, 29 ‘, 1PE10.3,’ :HIGH TEMP. FOR OPEN WINDOWS--HT CUTOFF (DEG F)’)

WRITE(13,910) (ICOEF(J).J=l. H)

910 FORMAT(’ INTEGERS — —’ % ,

#’,4X, ”VALUE’ ,4x,’Definition’/% -

, 1 ’ ,16,4x, ’ :HIGH TEMPERATURE STORAGE (MIX(2), NO MIX(l))’/%

,

2 ’ ,16 ,4X,’ :LOW TEMPERATUEE STORAGE (MIX(2), NO MIX(l))’/%

,

3 ’ ,16 ,4X,’ :BACKUP (FOSSIL FUEI,(0), ELECTRIC(l), BATH)’/%

,

4 “ ,16 ,4x,’ :SOLAR COLLECTOR (NONE(0),FP(l) ,1D(2), 2D(3),HEL(4))’ /%

.

5 ’ ,16 ,4X,’ :AIR CONDITIONING ON(1) OR OFF(2)’/%

6 ’ ,16,4X, ’ :REGULAR LOADS(0) OR SMOOTHED LOADS(l)’/%

,

7’, 16,4X,’ :SINGLE FAMILY(0), HIGH RISE(l), SHOPPING center’/%

.

8 ’ ,16,4x, ’ :BUY OFFPEAK ELECTRICITY (NO(0), YES(l))’)

1082 READ(12,*,PROMPT=,VAR. # AND VARIBLE: ‘) IV,V

IF (IV.LE.0) GO TO 1067

IF (IV.GT.30) GO TO 1082

COEF(IV)=V

GO TO 1082

1067 READ(l2,*,P ROMPT=

’VAR. # AND IVARIABLE: ‘) IV,I

IF (IV.LE.0) GO TO 1077

IF (IV.GT.8) GO To 1067

ICOEF(IV)-I

CO TO 1067

1077 READ(12,*,PRoMPT- ‘FILE NUMBER TO STORE SYSTEM COEFF: ‘) IV

IF (IV.LE.0) GO To 108O

REWIND IV

WRITE(IV) COEF,ICOEF

1080 CALL LOADS (TL,TH,FAN,HFATMX, COOLMX, ISMTH, IHR)

IF ((NHTQ.NE.1).OR. (HLHTH.LE.1.E-9) .OR. %

(HTQSTM.LE. lE-9)) GO TO 876

READ(5,*,PROMPT= %

‘HEAT LOSS FOR LT TANK OF HIGH TEMP STORAGE (KWH/DEG CENT/HR): ‘) %

HLHTL

876 IF ((NLTQ.NE. 1).OR. (HLLTH. LE.1.E-9).OR. %

(LTQSTM.LE. lE-9)) GO TO 877

TOTIO.PB-PNC/UGF002 08/17/78 14:41:56

1125.

1126.

1127.

1128.

1129.

1130.

1131.

1132.

1133.

1134.

1135.

1136.

1137.

1138.

1139.

1140.

1141.

1142.

1143.

1144.

1145.

1146.

1147.

1148.

1149.

1150.

1151.

1152.

1153.

1154.

1155.

1156.

1157.

1158.

1159.

1160.

1161.

1162.

1163.

1164.

1165.

1166.

1167.

1168.

1169.

1170.

1171.

1172.

1173.

1174.

1175.

1176.

1177.

1178.

1179.

1180.

1181.

1182.

1183.

1184.

READ(5,*,PROMPT- %

‘HEAT LOSS FOR LT TANK OF LOW TEMP STORAGE (KWH/DEG CENT/HR): ‘) %

HLLTL

877 ATEMPH=25

ATEMPL=25

IF ((HLHTH.GT.0).AND. (HTQSTM.GT.0)) %

READ(5,*,PROMPT=’ANBIENT TEMP. FOR HT STORAGE (DEG CENT): ‘) %

ATEMPH

IF ((HLLTH.GT.0).AND. (LTQSTM.GT.0)) %

READ(5,*,PROMPT-’AMBIENT TEMP. FOR LT STORAGE (DEG CENT): ‘) %

ATENPL

TEMP=HTLTS

IF (NHTQ.EQ.0) NHTQ-2

IF (NLTQ.EQ.0) NLTQ-2

IF (HTQSTM.GT.O.1) TEMP-HTHTS

IF (ISOLAR.NE.0) CALL COLL(ISYS)

IF (IOFFPK.EQ.1) CALL OFFPK

READ(12,*,PROMFT-’FILES FOR ELECTRIC H/C COP''S: ‘)IEH,IEC

IF (IEH.LE.0) Go TO 6654

REWIND IEH

READ(IEH) CPH

6654 IF (IEC.LE.0) GO TO 6655

REWIND IEC

READ(IEC) CPC

6655 00 114 1-1,25

IF (IEH.GT.0) cPH(2,1)-HcoPM*cPH(2,I) /(1-HcoPM*cPH(2,I)*FAN)

IF (IEC.GT.0) CPC(2,I)-CCOPM*CPC(2,I) /(I-2. 5*CCOPM*CPC(2,I)*FAN)

114 CONTINUE

READ(12,*,PROMPT-%

‘INITIAL VALUES OF LOW TEMP, HIGH TEMP, AND ELEC STORAGE (KWH): ‘) %

LTQSTO,HTQSTO,ESTOR

ESTORI-ESTOR

ESTO=ESTOR

LTQSTI-LTQSTO

LTQSO=LTQSTO

HTQSTI-HTQSTO

HTQSO=HTQSTO

EFFEX-1.

EFFLOT=l.O

EFFST-1.O

LTMIN-LTQSTM

HTMIN-HTQSTM

ESTMIN=ESTORM

EEFF-EFFPC*EFFBAT

KKK-1

Jl0-1 @FIRST MONTH

J20-12 @LAST MONTH

J30=1 @INTERVAL

K10-1 @FIRST HOUR

K2X-O @LAST HOUR-ZERO FOR WHOLE MONTH

K30-I @INTERVAL

1111 CONTINUE @CHANGE MONTHS AND HOURS HERE

~**************************************************************

% BEGIN CYCLING THROUGH THE MONTHS

%**************************************************************

DO 1000 I-J1O,J2O,J3O

M3-N(I+l)-M(I)

K20-K2X

IF (K2X.EQ.0) K20+M3

M31-(K20-K10+l)/K30 @ TOTAL HOURS IN THE MONTH
TOTI0.PB-PNC/UGFO02 08/17/78 14:41:56

1185.

1186.

1187.

1188.

1189.

1190.

1191.

1192.

1193.

119.$.

1195.

1196.

1197.

1198.

1199.

1200.

1201.

1202.

1203.

1204.

1205.

1206.

1207.

1208.

1209.

1210.

1211.

1212.

1213.

1214.

1215.

1216.

1217.

1218.

1219.

1220.

1221.

1222.

1223.

1224.

1225.

1226.

1227.

1228.

1229.

1230.

1231.

1232.

1233.

1234.

1235.

1236.

1237.

1238.

1239.

1240.

1241.

1242.

1243.

1244.

%**************************************************************

% BEGIN CYCLING THROUGH THE HOURS OF THE MONTH

%**************************************************************

DO 100 J-K10,K2O,K3O

K-M(I)+J-1 @ K IS THE HOUR OF THE YEAR

KCT-(K-1)/168

KCT-K-168*KCT

IDAY-l+(K-1)/24

QP-HWLOAD(KCT)*(1+0.372*COS (.017214*(IDAY-30)))

CALL LOADS1(K,EEE,QSH,TA)

TAIRF=-459.4+1. 8*TA

IF(QSH.GT.0. ) GO TO 20

QC=QSH @SETS QC POSITIVE FOR HEATING CASE

COPAA=l.0

COPEE=0

IF(IEH.GT.0) CALL COPT(TAIRF,CPH,COPEE)

GO TO 30

20 QC-QSH

IF (IA.EQ.2) QC=0

COPEE-0

COPAA-COPA

IF (IEC.GT.0) CALL COPT(TAIRF,CPC,COPEE)

30 IF(ISOLAR.EQ.0) GO TO 146

IF (HTQSTM.GE.0.1) GO TO 133

IF (LTQSTM.LE.0. l) GO TO 4140

F-LTQSTO/LTQSTM

IF (NLTQ.EQ.1) co TO 4135

TIN=LTLTS+F*(HTLTS-LTLTS )

GO TO 140

4135 TIN=LTLTS

IF (F.LT.0) TIN=LTLTS+F*(HTLTS-LTLTS )

GO TO 140

133 F-HTQSTO/HTQSTM

IF (NHTQ.EQ.1) GO TO 135

TIN=LTHTS+F*(HTHTS-LTHTS )

GO TO 140

135 TIN=LTHTS

IF (F.LT.0) TIN=LTHTS+F*(HTHTS-LTHTS)

GO TO 140

4140 TIN-LTLTS

140 IF ((LTQSTO.GT.O.99*LTQSTM) .AND. (COPAA.LE.0.001) .AND. %

(QSH.GE.0) .AND. (ISYS.EQ. 2)) TIN=TA-263

CALL COLL01(K,TIN,TEMP,TA,QSR, ESR)

AMQSR=AMAX1(AMQSR,QSR)

ANESR=AMAX1 (AMESR,ESR)

LX) TO 147

146 QSR=O

ESR=0

147 E(K)=0.

TESR=TESR+ESR

TQSR=TQSR+QSR

TEEE=TEEE+EEE

IF (QSH.GT.0) QCCM(14)-QCCM(14)+QC

IF (QSH.LT.0) QCHM(14)=QCHM(14)+QC

TQP=TQP+QP

TTEMP=TTEMP+TAIRF

IHRCT=IHRCT+l

EEEM(I)-EEE14(I)+EEE

QPM(I)-QPM(I)+QP

IF (QSH.GT.0) QCCM(I)=QCCM(I)+QC

TOTIO.PB-PNC/UGFO02 08/17/78 14:41:56

1245.

1246.

1247.

1248.

1249.

1250.

2000.

2001.

2002.

3000.

3001.

3002.

3003.

3004.

3005.

3006.

3007.

3008.

3009.

3010.

3011.

3012.

3013.

3014.

3015.

3016.

3017.

3018.

3019.

3020.

3021.

3022.

3023.

3024.

3025.

3026.

3027.

3028.

3029.

3030.

3031.

3032.

3033.

3034.

3035.

3036.

3037.

3038.

3039.

3040.

3041.

3042.

3043.

3044.

3045.

3046.

3047.

3048.

3049.

3050.

IF (QSH.LT.0) QCHM(I)-QCHM(I)+QC

QSRM(I)-QSRM(I)+QSR

ESRM(I)=ESRM(I )+ESR

TEMPM(I)-TEMPM(I)+TAIRF/M3 1

LTQSO=LTQSTO

HTQSO=HTQSTO

%********************************************************h*****

CALL SYSTEM(K,QSH)

%**************************************************************

IF (QSH.LE.0) GO TO 9911

QC1X-AMAX1 (QC1X,QC1)

QC2X=AMAX1(QC2X,QC2+QC2Z )

GO TO 9910

9911 QC1Y=M1(QC1Y,QC1)

QC2Y=AMAX1(QC2Y,QC2+QC2Z)

9910 IF (QSH.LT.0) QCIW=AMAXl (QClW,QCl+QC2tQC2Z)

IF (QSH.GT.0) QC2W=AMAX1 (QC2W, QC1+QC2+QC2Z)

IF (IGRID.NE.1) EHM=AMAXl (EHM,FFHW)

TBAT=TBAT+ESTOR

THTQ=THTQ+HTQSTO

TLTQ=TLTQ+LTQSTO

BOLMAX=AMAX1 (BOLMAX,FUEL-FUELII)

HTMAX-AMAX1 (HTMAX,HTQSTO)

HTMIN=AMIN1 (HTMIN,HTQSTO)

LTMAX-AMAX1 (LTMAX,LTQSTO)

LTMIN=AMIN1(LTMIN,LTQSTO)

ESTMAX=AMAX1 (ESTMAX,ESTOR)

ESTMIN=AMIN1 (ESTMIN,ESTOR)

IF (IGRID.EQ.0) GO TO 906

EKMAX=AMAX1( EKMAX,E(K))

EKMIN=AMIN1 (EKMIN,E(K))

906 FUELII=FUEL

LTQ-LTQSTO-LTQSO

ES=ESTOR-ESTO

ESTO=ESTOR

IF (LTQ.LT.0) GO TO 9400

LTQI=LTQI+LTQ

LTQIM=AMAX1 (LTQIM,LTQ)

GO TO 940l

9400 LTQ0=LTQ0-LTQ

LTQOM=AMAX1(LTQOM,-LTQ)

9401 IF (HTQ.LT.0) GO TO 9402

HTQI=HTQI+HTQ

HTQIM=AMAX1 (HTQIM,HTQ)

GO TO 9403

9402 HTQO=HTQ0-HTQ

HTQOM-MAX1 (HTQ0M,-HTQ)

9403 IF (ES.LT.0) GO TO 9404

ESI=ESI+ES

ESIM=AMAX1 (ESIM,ES)

CO TO 9405

940& ESO=ESO-ES

ESOM=AMAX1 (ESOM,-ES)

9405 IF (E(K) .LT.0) GO TO 7011

IF (IGRID.EQ.0) GO TO 101

TOTE=TOTE+E(K)

GO TO 101

7011 TOTS=TOTS-E(K)

101 ESM(I)=ESM(I)+ESTOR

IF (HTQSTM.LE.1.E-9) GO TO 3052

●

T

W)’

m
3051.

3052.

3053.

3054.

3055.

3056.

3057.

3058.

3059.

3060 .

3061.

3062.

3063 .

3064.

3065.

3066.

3067.

3068.

3069.

3070.

3071.

3072.

3073.

3074.

3075.

3076.

3077.

3078.

3079.

3080.

3081.

3082.

3083.

3084.

3085.

3086.

3087.

3088.

3089.

3090.

3091.

3092.

3093.

3094.

3095.

3096.

3097.

3098.

3099.

3100.

3101.

3102.

3103.

3104.

3105.

3106.

3107.

3108.

3109.

3110.

TOTIO. PB-PNC/UGFO02 08/17/78 14:41:56

3111.

3112.

3113.

3114.

3115.

3116.

3117.

3118.

3119.

3120.

3121.

3122.

3123.

3124.

3125.

3126.

3127.

3128.

3129.

3130.

3131.

3132.

3133.

3134.

3135.

3136.

3137.

3138.

3139.

3140.

3141.

3142.

3143.

3144.

3145.

3146.

3147.

3148.

3149.

3150.

3151.

3152.

3153.

3154.

3155.

3156.

3157.

3158.

3159.

3160.

CALL MMDDYY (INOM, IYAD, IRY)

CALL HHMMSS(IRH, INIM, ICES)

WRITE( 13, 2660) TITLE, INOM, IYAD, IRY

2660 FORMAT ( / /1X, 15A4 , ‘ DATE : ', 12,'- /, ,I2, '/' , 12)

WRITE (13,2666) IRH, INIM,ICES

2666 FORMAT ( 61 X , ‘ TIME: ‘,12, ’:’, 12, ’: ’,12/)

IF (ITBOUT. NE.1) GO TO 4112

IF (IPRINT. EQ.1) WRITE( 13,2777)

2777 FORMAT (/’ PHOTOVOLTAIC SYSTEM’)

IF (I PRINT .EQ.2) WHITE (13,2778)

2778 FORMAT (/’ HEAT ENGINE SYSTEM’)

IF (I PRINT .EQ.3) WRITE (13,2779)

2779 FORMAT (/’ HOT WATER SYSTEM’)

IF (I GRID. EQ.0) WRITE( 13,2780)

2780 FORMAT ( ‘ FOSSIL FUEL BACKUP’ )

IF (IGRID.EQ.1) WRITE(13,2781)

2781 FORMAT(’ ELECTRIC BACKUP’)

IF (IGRID.EQ.3) WRITE(13,2782)

2782 FORMAT(’ ELECTRIC AND FOSSIL FUEL BACKUP’)

IF (ISOLAR.NE.0) CALL COLL02

CALL LOADS2

IF (I0FFPK.EQ.1) CALL OFFPK2

IF (IOUTS.NE.1) GO TO 4112

WRITE(13,3) 3 FORMAT(//’ SYSTEM COEFFICIENTS:’ )

WRITE(13,909) (COEF(I), I=1,29)

WRITE(13,910) (ICOEF(I),I=1,8)

IF ISOLAR.EQ.0) GO TO 4112

WRITE(13,4) 4 FORMAT(//’ COLLECTOR COEFFICIENTS:’)

CALL COLL03

IF ((HTQSTM

.LE. IE-9).AND. (LTQSTM.LE. lE-9)) GO To 4112

WRITE(13,950)

950 FORMAT(//llX,’STORAGE HEAT LOSS COEFFICIENTS’ //2lX, %

‘HEAT LOSS’, 12x, ’AMB. TEMP’/l7x, ’(KWH/DEG CENT/HR)’> 7x, %

‘(DEG. CENT)’)

IF (NHTQ.EQ.2) WRITE(13,951) HLHTH,ATEMPH

951 FORMAT(’ HT STORAGE’,9X, 1PE10.3, 14X,0PF5.1)

IF (NHTQ.EQ.1) WRITE(13,952) HLHTH,HLHTL,ATEMPH

952 FORMAT(’ HT STORAGE”, 2X,1PE10. 3,’ --’, IPE10.3,8X,0PF5. 1)

IF (NLTQ.EQ.2) WRITE(13,953) HLLTH,ATEMPL

953 FORMAT(’ LT STORAGE’, 9X,1PE10.3, 14X,0PF5.1)

IF (NLTQ.EQ.1) WRITE(13,954) HLLTH,HLLTL,ATEMPL

954 FORMAT(’ LT STORAGE’,2X, 1PE10.3, ‘ --’, lPEI0.3,8x,OPF5.1)

IF ((NHTQ.EQ.1).OR. (NLTQ.EQ.1)) WRITE(13,955)

955 FORMAT(/' NOTE: FIRST HEAT LOSS NUMBER IS FOR HT TANK’ %

‘ OF THE PARTICULAR’/’ STORAGE; ‘, %

‘SECOND IS FOR LT TANK OF THE SAME STORAGE.’)

4112 CALL OUTTAB(ITBOUT, IHROUT)

END
OUTTAB . PB-PXL/L’Lk’002 08/ 17 / 78 14 : 44 : 5 1)

1.

2.

3.

4.

5.

6.

7.

8.

9.

10.

11.

12.

13.

1 000 .

1 000.

1 002.

1 003 .

1004.

1005.

1 006.

1007.

1008.

1009.

1010.

1011.

1 012. 

1() 13.

1014.

1015.

1016.

1017.

l018.

1019.

1020.

102 1 -

1022.

1023.

1024.

3000.

3001.

3002.

3001.

3004.

3005.

3006.

3007.

3008.

3009.

3010.

3011.

3012.

3013.

3014.

3015.

3016.

3017.

3018 .

3019 .

3020 .

3021.

, PRoGRAY ‘: A:ll; : iIL’ 1’ ~ 113. JB

‘< I{) H’, [ . L3L. LL

. FSFRG}’ PR(IGRAY

(J FF I C F () F TF(; H\() L(l(rY Ab 5 F S SYf-ST

L(o!.!PI LED

I)ATF : 1 I 1 217S

T I.ti F : 13 : b : 25

: PRL)L’NUI OUITAB . JB FLIR TABULAR IIUT PLT !7F DAT~

4/ BY :5 1!; C S ECME::T FD I T \ K1 \(, , TH 15 F’R(lGR *’[

d I L.L ALLoW U1’T PI.’ 1 OF” ALL DAT .4

5rF$ROL’T I \ P OL” 1 I AB ( ITB(3L1T , I tiR(j[’ ~ )

‘J 1‘4t/\ > I( Ih E ( t 7bo )

31‘ll-’(S [ (1:. k 1’L L’:{) ( 1.!) , T()’Tr.>f ( 12 ) , I tlTS!l ( 1 i!) , TALTF ( 12 )

!> LYE.:, b 1(3!: ESR!4 ( 12 ) , (j SLY ( 12 ) , QCCY ( 1.4) , (j(-HM ( 14 ) , LF I,k! ( 1 J ) , QP?~ ( 1 ? ) , L

Tr:tP~l ( L 2 ) , ILXP ( 1 L )

D I Y } \ b 1[)X L Ph ( 2, .! 5 ) , C P( ( 2, J ; )

!) IYE\ ‘, I IOY !_ S r ( 12 ) , LS E ( 12 ) , llSE ( 12 ) , 1 S!l ( 1 ? ) , L5L1 ( 12 ) , HSL1 [ I J )

I“IPi, IC 1 ~ PEAL(L)

C(l>CIL)Y / ANN /TF!i Pt’ 1 ( 10 ) , HTOST’I , T F.:l P\’ 2 ( ? ) , LTLjSTY , TL2iF’L’ 3 ( b ) , %

LS !(]KY > TE}lPL’4 ( 5 ) , FAN, T E!lPL’ 5 ( 3 ) , ITM P\’ 1 ( ? ) , IGR ID , ~:

IT’4P\’2 ( 5 )

( ol!l(l~: / CXXl /(”0 P,lA , LO PEE , EE}l , EB E)f , F“L. E , EFFEX , TE:; GY , RrSGM , I-X(;M , ;:

ESR , LS IfJR , EE FF , FFHW , FHE r , l-”IJEL , HTS STY, 1iTQ , HTQ1 , H ~Q[~ , %

YTQS() , HTQSTO , LT(!I , 1 T(~[) , LT(~SO , LT(/STLl , QA, Q(” , (/(; 1, (2C ? , ‘<

(j(2L , QE , QP , QS , (jSR , RES 1L19 , SHLT , ST!IET , TOTTF’(1 , rO rB E(1 , i

IL) 1 F-[), HLHT L, HILT L, LFP”LL)T, EFF ST, I PR I)w T

CL)>INO’, / D.XXX /BOLHAX , C K , C PH , EEEM , EH!! , EKX4X , EKXIN , ES C , ES I , F.S LY , ;.

ES}l , LSO , ESO?l , ESR!.1 , F’STXAX , EST?l I\ , FST{OR I , FL’ LL!NL) , ‘!

W RL’\, HS F, FiSH, HT:!Ax, HTLl IS, HTtj I Y, HT,~LIY, HT(j ST I , ‘,

IEC , I EN , I F,(JMST , IHRAV , IHRCT , Ic)UTS , J 10, J? 0, J j(l , 1,S k, , LS!I , ‘.

LTYAX> LTx I>; , LTQI!l, 1. T(jo&l , LTQST L , &[ESR , AXQSR, QW?l, QcN?f, “i

QL 1!+”, C& 1 X , Q(- 1 }’ , QL 2W , QC 2X , LQC .!Y , QF’I , (JSRY , rALT L , TBAT , Z

TEEE , TE?t PY , TCSR , THTQ , TLTQ , T(1 Tr , N) 1 EN, TOTS, TOTS}!, .

TQP , TQSR , T L’LMP

LL12C.l[IS /XDATA/ F , HKLo AD

IF ( ITBOrT . !1 .1 ) C.(I TO 5000

I F ( I ~lLTs. Yr. 1 ) L,(I ro J(1 I I

IF [ [ I F N . L I .1 ) . AXD . ( I EC . LT .1 ) ) LO TCI 2’) 11

.*** ******************* ● ********************** ● ****************

‘h R IT E ( 1 3, .?.! )

?: FORMAT ( / / 7X, ‘ EL ECTR I (- H / , (’\l 1’ ‘ ‘ S ( Kh’H /K’Jl{ ) “ )

!, SIT k ( I 3, 23 )

.!3 p OK}lA I (4X, ‘ TEMP ‘ ,4X, ‘ HEAT ‘ ,8X , ‘ Tt :4 P ‘ , .,.\, ‘ L{klL ‘ )

1(-S =0

1}:s =[1

I F ( 1 f L . LI .1 ) I (“ :>= 1

1 F ( LEH. LT .1 ) 14S= 1

D() 119 1 = 1, 2‘,

I F ( C PL ( 1, I ) .1. I . -9~ . ) I C S = 1

I F ( L“ PR ( I , I ) . L 1.-99. ) I IIS = 1

IF ( ( 1 I(S . r(j .1 ) . AXL) . ( I [ S . k [J. 1 ) ) (;0 T( 1 20 I 1

1 F ( ( I tiS . YE . 1 ) . ,12.1) . ( 1(’ b . \F . 1 ) ) h’k IT F ( 1 ; , .!+ )

~- Pl{ ( 1 , I ) , ( PH ( : , I ) / ( I +( Pi: ( : , I ) *r,\!, ) , -,

[- }’( ( 1, I 1, [ F1- ( ; , I ) ‘ ( 1 +.7. 5*C PI- ( 2, 1 ) * F }:, )

I F ( I [’ S . F G .1 ) k’R IT [- ( I 3, 2 ] ) ( I]ti ( 1 , I ) , ( F’11 ( J , I I / ( 1 +4 1’H ( J , I ) * t 1:, I

I F ( IRS . F(I .1 ) h~ I r E ( 13, .2b ) ~ [’( ( 1 , I ) , (’ P( ( .’, I ) / ( I +2 . 5*, 1’( ( ? , L ) * F A:, )

11 Y [ LIN i 1.\L E

OUTTAB .PB-PNC/UGFO02 08/ 17/78 14: 44: 51

3022.

3023.

3024.

3025.

3026.

3027.

3028.

3029.

3030.

3031.

3032.

3033.

3034.

3035.

3036.

3037.

3038.

3039.

3040.

3041.

3042.

3043.

3044.

3045.

3046.

3047.

3048.

3049.

3050.

3051.

3052.

3053.

3054.

3055.

3056.

3057.

3058.

3059.

3060.

3061.

3062.

3063.

3064.

3065.

3066.

3067.

3068.

3069.

3070.

3071.

3072.

3073.

3074.

3075.

3076.

3077.

3078.

3079.

3080.

3081.

24 FOFL??AT ( 3X, F 5.1, 2X, Fb .2, 7X, F5 .1, 2X, Fb . ‘2)

25 FORMAT ( 3X, F5 .1, 2X, Fb .2, 9X, ‘ --’ , 6x, ‘ --’ )

26 FORMAT ( 5X, ‘ --’ , 6X, ‘ --’ ,8X, F5 .1, ~x, Ffi . ~ )

Z**** ************************** ***** ***************************

2011 EFACT=AMAX1 ( 1, ESTORY)

BATLF=TFIAT/ (HRRLJw*EFAcT )

EFACT=MIAX 1 ( 1, HTQST?l)

HTLF=T}lTQ/ ( HRRUN*EFACT )

EFACT=LYAX 1 ( 1, LT(/STM )

LTLF=TLTQ/ (HRRLW*EFAGT )

EFACT=A!!Xl ( 1 ,TENGM)

ENGLFT=TOTTEO/ (HRRLIN*LFACT )

EFACT=AMAX1 ( 1, BENGM)

ENG LFIj=TOTBEO/ ( HRRL1’*EFACT )

EFACT=N4AX1 ( 1, ENGM)

ENGLF=TOTEO/ ( HRRUN*EFACT )

EFACT=O

Do 4110 I= JIO, J20, J30

Ik- (A8S (TALTE ( I ) ) .LE. 1.00) TALTE ( I ) =o

4110 EFACT=EFACT+TALTE ( I )

WRITE (13 ,4113 )

4113 FORMKT ( / / 7X, ‘ ELECTRICITY AND FOSS 11, FUEL BACKITP DF:!.lAsD5 (KKII ) ‘ )

WRITE ( 13, 1005)

1005 FORMAT ( ‘ MONTH’ , 4X, ‘ ELEC . BUY ‘ , 4X, ‘ ELEC . SF. LL ‘ ,4X , ‘ FLF 1 i’SL ‘ , :!

3X, ‘ EXCESS LT ENERGY’ )

WRITE ( 13, 1006) (1, TOTEM(I) , TOTSM ( L), FUEL11O ( I ), T.4LTE ( I ) , I= 110, J.10, J 30 )

1006 FORMAT( ‘ ‘ ,13, 4X, IPE 10.3, 4x, IPE 10.3, 4X, IPE 10.3, 5X, 1 PL 10.3 )

WRITE ( 13, 1007) TOTE, TOTS, FUEL, EFACT

1007 FORMAT ( ‘ TOTAL’ , 2X, IPE 10.3, 4X, IPE 10.3, 4X, IPE 10.3, 5X, IPE 10. j )

IF ( ( IGRID . EQ . O) .m’D . ( I PRINT . EQ. 1 ) ) WRITE ( 13, 4007)

4007 FORMAT ( ‘ NOTE: ELEC SELL IS DC EI,ECTR IC ITY THAT CAS ‘ ‘ T ‘ , Z

‘BE STORED IN THE BATTER}” )

%****************** ******************** ********************  

Qcmi( 1 3)= QcHM( L4 ) /lHRCT

QCCH( 13)=QCCM( 14) /IHRCT

Do 66 1=1, 14

TEST=QCCM ( I )

IF (QCHM ( I ) .GT. QCCM( I ) ) TEST= QCHM( I )

IN 65 J=l , 10

IF (TEST/( 10** J) . LT .1. 00) GO TO 64

65 CONT INL!E

64 IEXP ( I ) =J-1

DI V= 10** (J-1 )

QCHM ( L ) =QCHM ( I ) /D IL’

QCCM( I )= QCCM(I ) /D IV

66 CONTINUE

IF ( IHRAV. NE. 1 ) GO TO 9059

WF. ITr ( 13, 7 705)

7705 FORMAT (// 26x , ‘TOTAL ?lONTHL}. b’,\LL’k, S (KWH ) ‘ , 24X, ‘ AVER ‘ / ;.

7X, ‘ PHOTO VOLT’ ,6X , ‘ SOLAR ‘ ,6X , ‘ ,

, %

‘ INTERNAL DEMANDS ‘ , ‘

———

— - ‘ , 7X, ‘ TE}l P ‘ / Z

‘ ?IONTH ‘ , lx, ‘ ELECTRIC ‘ ,6X , ‘ THERWIL ‘ , 5x, ‘ FL~;cTRIc “ , ;:

5x, “ HEAT/COOL , 5x, ‘HO r WATER , 7X, ‘ (F. ) ‘ )

WRLTL ( 13, 7707) (1, ESRY( L ) , QSR?l ( I ) , EEE$! ( I ) , QCHM( I ) , QCL?I( I ) , “i

IrXk’ ( I ) , QPH ( I ) , TEXP!4 ( I ) , 1=.J 10, J2(I , J 30)

7707 FORMAT ( ( ‘ ‘ , 1 X , I ? , 2X, ? ( 1 PF 10.3, )X) , 1 Pr 10.3, 2X, OPF4 .2, ‘ / ‘ , ‘.

OPF4 .2, ‘ L+oo ‘ , T 57, T 1, 2X, IPE I (]. 3, 7X, opFL . I ) )

zwR I r L ( 1 3, 7710 ) TF SR / I HRCT, TQSR/ I HR(-T, TELE/ I t{Rr T, Qcw ( 13 ) , ‘.

% QL,C?I ( 13 ) , T EXP ( 13 ) , TQP/ IliR(”T , 1 rE?lP/IHRCT

%7 710 FORMAT ( ‘ YR AC’ ‘ , 2 ( 1 PE 10. 3, 3X ) , 1 PL 10. 3, 2X, OP F4 . .? , ‘ / ‘ , ;.
( ]1 TT iF3 . P’E -!J\[ / L L Fi]II J ) ‘ 1 - 

; h I I : + 4 : $1

, 7X, —’ , ‘OF S ~oRAC 1’ ( KWll ) ‘ , ‘ - 7/

— *’=

3X, ‘ ‘ , ‘ []F STOW{(, I ( hWll ~ ‘ , ‘ — .—‘1 -

‘ !’10s rH ‘ , 1 x ,– “:

E> IV , I rfj 1‘1 , ~iTI

]1‘1

‘ MAX1yL~l I YF’L’; 1‘, 1,, ~1( ( hWH/HR ) : ‘ , 1x, 3 ( :x, 1 PI 10.3, 2X) )

F s(I:1 , LTQON , HT(~)Fl

OLTTTAL3 . PB-PNC /rGFOO 2 08 / 17 / 78 1 i : +~ : 51

3142.

31L3.

3144-

3145.

314b.

3147.

3148.

3149.

3150.

3151.

31 5.?.

3153.

3154.

3155.

3156.

3157.

3158.

3159.

3160.

3161.

3162.

3163.

3164.

3165.

3166.

3167.

3168.

3169.

3170.

3171.

3172.

3173.

3174.

3175.

317b .

3177.

3178.

3179.

3180.

800b FORMAT ( ‘ *NOTL : LOAD FACTOR 13 ASEL~ ON AC T1’AL ?IAX 1 YIY ‘ , ‘

,

, NUT \l!i DFS IGN MAXI VL’?l . ‘ )

;:******** ● ********* ********** ● ********* ********** **********  

8056 WRITE ( 13, 107 I )

ln71 FORMAT ( / / 23X, ‘ MAX I’4[T1 SPA~ L CtlND IT 10S 1 \C LOADS ‘ /

21X, ‘ ELECTRIC ‘ , 7X, ‘ THE, RMAI. ’ , XX, ‘ L_OTA1 ‘ )

WRITE ( 13, 9011 ) QC 1X, QL 2X, QC ?k’ , (L)C 1 Y , [~[; 2Y , QC IJ

9011 FORMAT ( ‘ CL>OI,l NG ( L’3JH ) : ‘ , LX, 3 (2X, 1 pr 1 c. 3, 2X 1 / ‘j

‘ HEATING (KWH ) : ‘ , !+X , 3 ( :X, 1 I’E 10.3, 2X) )

;:** ******** ********** ********** ********** ********** ********** **

WRITE ( 13, 8886) A..QSR , A.. ESK

13H8b FORMAT ( / / “ MAXl?lLM SOT, AR THERMAL (l[TT PLIT ( Kh’11 ) : ‘ , 1 PI I () .1 / “.

‘ NAXI?fl. I?l SOLAR ELECTRIC OL’T PUT ( KWH ) : ‘ , 1 PF 10.1 )

WRITE ( 13, 3031 ) EB E?i

3031 FORMA1 ( ‘ MASIYLIM ENC INF BOILER (01’ TPL’T (Kh’H ) : ‘ , 1‘PE 10. i )

WRITE ( 13, 302(3) EB!I

30?0 FORWT ( ‘ MAXT!4LT1 NONENC INE BOILER (01’ TPL’T (KWH ) : ‘ , IFL 1 C . 1 )

WRITE ( 13, 3914 ) CHM

3914 FORMAr ( ‘ MAXIMUM HOT WArER FL’k L LISI’ (Kk’H ) : ‘ 1 Pr 1 (). 3 )

WRIT E ( 13, 8862) FHET , SHET , STHFT

88 b.? FoRMAT ( ‘ F(3S S IL HEA 1 PI.’T INTtl k;NG INE ( KWH ) : ‘ , 1 PE 10.3 / ‘.

‘ SOLAR HEAT PL!T INTO L-. NG1SE (Kh’H ) : ‘ , 1 PE 1 fl . 3/ ;;

‘ STORAGE HEAT P(’T INTo } NCI!YL ( KWH ) : ‘ , IPE 10.3 )

WRITE ( 13, 1086) ERMAX, -El@l IN

108b FORMAT ( ‘ MAXLMLTl ELE[”TRICI rY BOL;GH1’ IN AN HL)L:R ( K’.J1i ) : ‘ 1 Pt 10. 3“

/ ‘ MAXI?fLP4 ELEC rRICITY sO1.D IN AS H017L (hWH) : ‘ , IPE 1[1 .3 )

k’RITE ( 13, 1020) BOLMAX

lo~o FORMAT ( ‘ MAXIMUM FUEL BOUGMT 1X AS HOUR (KWH ) : ., IPL 10. 3 )

IF ( LGRID . EQ. O ) TOT S=0

WRITE ( 13, 4091 ) TO rE, ru rs, FUEL

4091 FORMAT ( ‘ TOTAL ELECTRICITY l\ OLJGHT ( KWH ) : ‘ , IPL 10. 3/“>

‘ TOTAL ELECTRICITY SCILD ( Kh’H ) : ‘ , 1‘i’E 10. 3/ ‘[

‘ TOTAL FUEL BOUGHT (KWH ) : ‘ , IL’F’ 10. 3//// )

%  ** ******************** ***** *********************** ********

IF ( IHROUT .NE .1 ) GO TO 4000

5000 WRIIE ( 50 ) E, AMQSR, AIMESR @ollT pUT F[)K [TT ILITY ,\ N,\L1-S I S

X******************** ********************** ********************

4000 RETIJRN

END
LOAD S. PB-t’NC/L’GFO02 08/17/78 14:44: 17

1.

2.

3.

‘J.

5.

6.

7.

8.

Y.

10.

Il.

1:.

3.

000.

001.

002.

003.

004.

005.

(lob .

1007.

1008.

1009.

1010.

1011.

1012.

1() 13.

1014.

1015.

1016.

1017.

1018.

1019.

lo~o.

1021.

1022.

1023.

1 (3’24 .

1025.

lo~6.

lo~ 7.

lo~~ .

1029.

1030.

1031.

1032.

1033.

1034.

1035.

1036.

1037.

I 038.

1039.

10 4(I .

1041.

I 04 ? .

1041.

1044.

1045.

1[04 6.

‘< PROCRAM NAME: LOADS. JB

Z JOHN C. BELL

‘: F. FF.RGY PROGRAM

;: oFF ICE OF TECHNOLOGY ASSESSMENT

;. COMP I LED

x DATE : 1 I 27178

,, TIME: 17:29:26

;: PROGRAM LOADS. JB FOR SETTING UP rHE ELECTRIC, THERMAL, AND

;. PRoCESS LOADS FOR: SINGLE FAMLLY, TOWNHOUSE, OR

LOW RISE APARTMENT BUILDINGS; HIGH RISE APARTMENT

-/,. BUILDINGS; OR, SHOPPING CENTERS

,/

,,

;LIBKOUTINE LOADS(TL,TH,FAN,HEATMX,COOLMX, ISNTH, lHR)

DIMENSION ELI.0AD(168),ELOAD1 (24) ,ELOAD2(24),WLOAD I(24) , %

WLOAI)2(24),HWLOAD( 168) ,E(8760),TA1 (8760)

COMMON/XDATA/E,HWLOAD

!-QUIVALENCE (ELoAD1( l),ELLOAD(l )), (EL0AD2(1),ELL0AD( 145)), Z

(WI,OAD1(l ),HWLOAD(I)) ,(wLoAD2( 1),HwLoAD(145))

,>

Z SET UP LOADS FOR HOURLY COMPUTATION

READ(25) TA1,TA1

IF (IS?fTH.EQ.1) GO TO 6 0 1

READ(20) E, ELOAD1, ELOAD2,WLOAD1 ,WLOAD2

Kcr=o

DO 600 1=25,144

KCT=KCT+I

IF (KLT.EQ.25) KCT-1

HWLOAD(L)=WLOAD1 (KCT)

ELLOAD(I)=ELOAD1 (KCT)

600 CONTINUE

CO TO 701

bol READ(20) E,ELLOAD,HWLOAD

701 KCT=O SZERO 14EANS THE YEAR STAHTS ON MONDAY AS THE 168 MAT. DO

TI.LIAD=O. O

IF (IHR.NE.0) GO TO 602

F’ANH=FAN*HEAT}lX

FA!!C=.?. 5*FAN*COOLMX

GO TO 702

602 KEAO(12,*,PROMPT= z

‘MAXIMUM PUMP/FW” LOAD--HEATING, COOLING (KW FAN/TOTAL OUTPUT): ‘) %

FANH,FANC

FANHH=-FANH*HEATYX

FANCC=FANC*COOLMX

70~ TLl=(459.4+TL)/l.8

TH1=0.001+(459. 4+TH) /1.8

KCT=O

RETURN

“,

(.

L SET UP LOADS FOR EACH HOUR

&iTRY LOADS I(K,EEE,QSH,TA)

~A=TAl(K)

KLT=KCT+l

IF (KCT.GE. 169) KCT=l

iF (IHR.EQ.2) CO TO 444

IF ((TA.GE.TL1 ).A??D. (TA.LE.THI )) GO TO 900

IF [(TA.LT.TL1 ).AND. (TLOAD+F (K).GT.0)) GO TO 900

IF ((TA.GT.THl ).AND. (TLOAD+E (K).LT.0)) GO TO 900

LOADS.PB-PNC/UGFO02 08/17/78 14:4k:17

1047.

1048.

1049.

1050.

1051.

1052.

1053.

1054.

1055.

1056.

1057.

1058.

1059.

1060.

1061.

1062.

1063.

1064.

1065.

1066.

1067.

1068.

1069.

1070.

1071.

1072.

1073.

1074.

1075.

1076.

1077.

1078.

1079.

1080.

1081.

1082.

1083.

1084.

1085.

1086.

1087.

1088.

1089.

1090.

1091.

1092.

1093.

1094.

1095.

1096.

1097.

444 TLOAD=TLOAD+E(K)

IF (IHR.NE.2) GO TO 704

KJ3AY=l+(KCT-1) /24

KHRD=KCT-(KDAY-l )*24

KDAY-KDAY-7*( (KDAY-1)/7)

IF ((KDAY.LE.6).AND. ((KHRD.LT.8)

(TLOAD.GT.0)) TLOAD=O

IF ((KDAY.EQ. 7).AND. ((KHRD. LT.13

(TLOAD.GT.0)) TLOAD=O

IF (((K.LE.5831).AND. (K.GT. 3625)

.AND. (TLOAD.LT.0) ) TLOAD=O

OR. (KHRD.GE.23)).AND. %

.OR.(KHRO.GT. 19)).AND. %

.AND. ((KHRD.LT.8) .OR. (KHRD.GE.23)) %

IF (ABS(TLOAD) .LT.O.0001) GO TO 40

FANH=FANHH/TLOAD

FANC=FANCC/TLOAD

704 IF (TLOAD.GT.0) GO TO 20

PCLD=-TLOAD/HEATMX

IF ((PCLD-O.1).LT.0) GO TO 40

EEE=ELLOAD(KCT)+FANH*PCLD

QSH=TLOAD

TLOAD=O.O

GO TO 800

20 PCLD=TLOAD/CDOLMX

IF ((PCLD-O.1).LT.0) GO TO 40

EEE=ELLOAD(KCT)+FANC*PCLD

QSH=TLOAD

TLOAD=O.O

GO TO 800

900 TLOAD=O

40 EEE=ELLOAD(KCT)

QSH=O

800 RETURN

z

% OUTPUT STATEMENTS

k

ENTRY LOAOS2

IF (IHR.EQ.0) WRITE(13,959)

959 FORMAT( - LOADS SET UP FOR SINGLE FAMLLY HOUSE’)

IF (IHR.EQ.1) WRITE(13,960)

960 FORMAT(’ LOADS SET UP FOR HIGH RISE APARTMENT BUILDING’)

IF (IHR.EQ.2) WRITE(13,970)

970 FORMAT(’ LOADS SET UP FOR SHOPPING CENTER’)

IF ((IRR.NE.O) .AND.(FAN.GT. O)) WRITE(13,961)

961 FORMAT(’ CAUTION: FAN LOAD (#27) IS NOT ZERO’)

WRITE(13,971)

971 FORMAT(’ THE MISCELLANEOUS ELECTRIC LOADS AND THE HOT WATER LOADS’)

IF (IS~H.EQ,O) wRITE(13,972)

972 FORMAT(” ARE NOT SMOOTHED’)

IF (ISMTH.EQ.1) WRITE(13,973)

973 FORYAT(’ ARE SMCK3THED’)

RETURN

END
L’PDATL. PB-PN(-,’[’C; l’(IOZ 08/17/78 14: 49:43

1.

. .

~.

4.

1. h.

7.

8.

9.

I 0.

11.

1?.

1 ).

l!l.

1~.

16.

17.

I 8.

19.

20.

21.

J:.

23.

:4 .

25.

2(300 .

2001 .

2002 .

,1003.

2004.

1005.

1006.

2007.

2008.

S 1 ZE=ENERG}’ STCIKAGE CAPACITY

CLRRN1’=MIO[~T OF ENERGY C[RRENTLY IN STORAGE

L) LLTA=ENERGY ADDED TO STORAGE (IF POSITIVE)

DE LTA=ENERGY REMOVED FROM STOi%iGE (IF NEGATIVE)

RES ID= ENERGY WHICH CAN NOT BE STORED (IF NEGATIVE 1

RESID=ENERGY WHICH CAN NOT BE PROVIDED FROM S’GOF.AGE

(IF POSITIVE)

EFFPC 1=ONE-WAY EFFICIENCY OF POWER CONDITIONER

OR HEAT EXCHANGER

EFFBT=TWO-WAY BATTERY OR THrR?L\l >TORAGE EFFIL [E!iCY

S UBRO[lT- 1 NE ~,p[lATE (s I; F , CL~R~T , DP I TA, RrS I D , rFF P( 1, EF F-FIT, PCS IZ 1 )

I F ( S I ~ E . GT . (]. (] I ) GLI [ L) H(1O

RES ID=<DEL~ \

CURRNT-+ . (>

RETURN

800 ~FS I i)=Ll

IF ( (C[_RR\l , (. F . j ILL , .AND . {D! LTA , GT .0 ) ) GO r{) 700

IF ( (CLTR\ 1. IF_. 0.00 ) .<13D . ( DELTA, LT .0 ) ) GO TO 700

IF (ABS ( t I T\} .1 T .0. 0001 ) RETURN

UPDATE. PB-PNC/UGFO02 08/17/78 14: 49: 43

2009.

?Olu.

?fll 1 .

2012 .

’201 3.

2014.

Jo 15.

2016.

2017.

:0 18.

201 ~.

2020.

.!02 1 .

20.2:.

:02 3.

:U?4 .

: [02 5.

2026.

~oJ 7.

2 0.!8 .

2029.

JC 30.

2031.

.! 01 ? .

2033.

2034.

2035.

2036.

2037.

2038.

2039.

2040.

2041.

2042.

IF (DELrA. LT . O)(XO TO 100

TESTO=DEL,TA-PCSIZ ~ /EFFPC 1

IF(TESTO. GT. O )CO TO 50

TEST 1= EFFPC 1 *EFFBT*DELTA+CURRNT

IF ( TEST 1. GT . S IZE )GO TO 20

CL’RRNT =TEST 1

Kk.TURN

20 RES ID= ( S 12 E-C LJRRNT -EFFPC 1•EFFBT*DELTA ) / ( EFFPC

LL’RRNT =S IZE

RETLIR!i

50 TF,ST l= EFFFiT*PLS17. LtCL!RRNT

1P’ ( rP’ST2 . GT . S1 Z E )C() TO 20

RFSID= ( -1 ) *TES rO

LLTRRNT =TEST 2

RETllRN

100 IF ( ( OELTA+PCS IZ I ) . L,T .0 )GO TO 150

TEST j=DI LTA+EFE’PC 1 *CLKRNT

IF (TLST j . LT .0 IGO TO 120

cLJR~”T=DP: LTA/EFFPC 1 +CURRNT

RETURN

1 ~o REs ID= (–1 ) *TEsT3

C ~llRNT=O

RETVRK

150 TEST4=CIJRRNT-PCS121 / EFFPC 1

IF ( rt’,ST4 . LT . O)GO TO 220

RES ID=- (DELTA+ PCSIZ 1 )

CURRNT-TEST4

RETURN

220 RESID=-DELTA-EFFPC 1* CURRNT

CURRNT=O

RETURN

700 RESID--DELTA

RETURN

END

*EFFB r )

.

-7

m

●
CUPT.PB-PNL/LiGFO02 08/17/78 1L:4H:40

1.

2.

3.

4.

5.

6.

7.

8.

9.

10.

11.

12.

13.

1000.

1001.

% PROGRAM NA..E: COPT.JB

Z JOHN C. BELL

,.“ ENERGY PROGRAW

Z IJE. F ICE [0 E“ ‘L EC HNOLOGY ASS ES SMENT

;( COMPILED

z DATE : L21LOJ77

z TIME : 14 : 10 : 24

% PROGRAM CO PT. J B FOR OFT ERM I!i ING THE COP ( EFF ) FoR A

z GI V17i rEMPERAT~’RE ( T ) F’ROX Tll F COP CL-R Vr ( C P ( 2, 25 ) )

z

z

%

;:

SUBROUTINE COPT (T ,CP ,.EFF )

DIMENS 10N CP ( 2, 25)

.

LOPT . PB-PNL /1.’CF 0[> 2 OX/ 17/ 78 1 + : 48 : 4()

1002.

1003.

1004.

1005.

1006.

1007.

1008.

1009.

1010.

101 i.

1012.

1() 13.

1014.

1015.

IF (T. LE. c p ( 1, 1 ) ) GO TO 11,2

DO 14 I= 1, 25

IF (CP ( 1, I ) . LT .-99. ) GO TO 113

1X=1

IF ( (T. GE . CP ( 1, I ) ) . AND. (T. LT . CP ( 1, I+ 1 ) ) ) (;[) IO 111

14 CON’! INUE

111 EFF=(, P(2,1)+(LP(?, I+1 )-L P(?, I) ) Z

* (T-CP ( 1, I ) ) / ( CP ( 1, 1+1 ) -CP ( 1, I ) )

RETURN

11~ EFF=cp(~, l )

RETURN

113 LFF=C P ( 2, LX)

RETURN

END
1.

.!.

i.

+.

~.

h.

7.

k .

Y.

1 [).

[1.

12.

1000.

1001.

1 OLI 2.

1003.

1 0(14.

1 (JU5 .

100b .

1 0[1 ? .

Ioox.

1009.

1010.

1011.

1012.

1013.

1014.

2000.

2001.

2002.

2003.

2004.

.?Oof .

?006 .

?()() 7 .

2008.

2r)OY .

Zn I 0,

.?() 11 .

201 1 .

2013.

2014.

2015.

201 b .

.?() 1 / .

201 H .

2019.

:rr?o.

202 ] .

‘! [122 .

2023.

2024.

? 025 .

2026.

2027.

2028.

2029.

1030.

2031.

?0 32.

51 UBROLIT IN E SYS r EM ( K , (JSH )

D I!.lLNS ION E ( ~7bo ) , H~L()/+D [ 1 b~ )

I?t PL IL ~r RCAI, (L )

L O?ti[~N /AXXX/COP,\ , EHWEFF , Hco P!.1 , CC(IPM , EFFB , ENCMAX , Eb. F 1, FF F? , ALPHA 1, %

ALPHA2 , HTQST?I , LTHTS , HTHTS , L TQsT?l , I TLTS , 1lT LTS , HLH 1 H , “:

FHWEFi’ , HLLTH , F’FFBE , ES rORY , t FFBA1” , F’(’ S 12, EFi-” PC , HEA 1’MX , Z

COULNX , FAN , TL , 1 H , XXX, NHT(/ , Xl T~J , IGR J 1), Is~l LAR , IA, I SMTH , ;:

I HR , IOE’FPK

LOMMON /L XIX / [’[1 PAA , c() [Jr E , t BY,, EBEM , 1“ FE , Et’ FEx , TF, NCM , B P NGM , FNGM , ~:

E<R , ES rUR , EE P’F , FL- Hh” , Fli EI , F[’EL , H rSSTY , HTQ , HTQ1 , H I’QO , %

IIT(/S( 1, HT(?s1 (1 , LT(~ 1, L T[Y7 , L rQSCI , L 1 (j ST(l , (2A, Q(” , QC 1, QC 2, X

()(’: / , ( )E , (~}, , ,2>, [~\R , RES [ Dq , SHF T , STH t T , TLI rTEO , TOTBEO , %

TO T1-LJ , H1. HTL , HLLTL , LF” F[ (1T , F F’FST , L PRINT

Co!@tON IDAT i / E , Hk’I (1 AI)

DA I A I PR [ :, 1, z /

Q(- 1 =[)

QC2=0

IQC?=l

QHOOR= OF I

I F (U) P u. f r. (1. 001 ) G~] T(1 32

IQHOI.’k= (; P+UL / (-(OPAA

32 C ALL 1’ POATE ( L r(JSTY , LT(~STt) , -QHOUR, RESIL)Q, EFFE.X ,EFFLOT, LTQSTM)

QP 1 =&l\x 1 ( 0, QFI- ((j HLlrR-RE, s T L)Q ) )

IF ( QP ] .Lh. O.001 ) QC=[2C-COPAA* (QHOUR-RES IDQ-QP )

QP=QP 1

I F ( (!SH . GT . Cl ) QC2Z=QSH-QC

IF ( QSH . LE .0 ) QC2Z=-Q5H-QC

:* *** ******* **&********** ************ *********** *********** * *

>*********************** ************************* ************

;**** * ~{EAT ~NC INE SE(:T ION--VERY C(}MPL ILATF. D ! ! !

.,* *** ************** ************** **• ******** ** ● **************

;(   ** ******* ********** ● ******** ********* ********* ********* *

SUL C=@R+H r(JsT(~

H rQSTLl=(3

IF ( SO1, ! . CT . QP ) GO TO ? 000

‘! .20’? QF’=QL’-SO[. E

SOL F=()

Q( 1 =Qc

IF ((~SH . GT .0 ) QC?=QSH-QC

I F ((JS}l . 1.F .0 ) QC.?=-QSH-QC

E{) LIT+O

Iqc 2-0

EEE=E,EEtQP/EHWEk”F

QP=O

GO T(I 900

200(3 IF (COPAA. CT .0.01 ) GO T(3 2100

(/C 1 =(/(;

co [’Q= 1.0

HESYS. PB-PNC/UGFO02 08/ 1 7/78 14: 43: 37

2033.

2034.

2035.

203b .

2037.

2038.

2039.

2040.

2041.

2042.

2043.

2044.

2045.

2046.

2047.

2048.

2049.

2050.

2051.

2052.

2053.

2054.

2055.

2056.

2057.

2058.

2059.

2060.

2061.

2062.

2063.

2064.

2065.

2066.

2067.

2068.

2069.

2070.

2071.

2072.

2073,

2074.

207S .

2076.

2077.

2078.

2079.

2080.

2081.

2082.

2083.

2084.

2085.

2086.

2087.

2088.

2089.

2090.

2091.

2092.

~**** *******************+  ** *** ************************* **

z***** C.&~ THE BOTTOM L!N’G [-YLLF BE {ON ALL I H r WAY

Z  ** ************************ ***** *************************

~~o 1 IF (QF . GT . SOLE*Eh’F 1 *ALPHA.! ) (,0 TO 2001

BETAV= 1

GAMMA= 1

GO ro 2050

Z******************** ********************** ******************

%***** cAN THF BoTTOMING CYCLE BE ON FART ~AY?

Z****************** ******************** ******************** **

?00 1 IF ( QP. CT. SOLE* EFF 1 * (ALPHA 1+ALPHA ? ) ) GO r(l .? Oo2

BETAV=l

GAMMA= ( SOLE *F.FF 1* ( ALT’HA1+ALPWI? ) -QP ) / ( SO LF*EFF 1 *ALpHA 1 )

GO TO 2050

Z**** ************************** ***** *************************

%***** BOTTOMING CycLE OFF !

y~* ******* ********** ********** ● ********* *********** ********** *

2002 BETAV= ( SO LF-QP ) / ( SOLE* ( 1 -EFE’ 1 * (ALPHA 1 +ALPHA? ) ) )

GAMMA=O

%**** ************************** ***** *************************

%***** CHECK FOR ENGINE CLIPP INC

Z  ** ********************** ***** ************************* **

2050 IF ( BETAV*SOLE*EFF1 .GT . ENGMAX) GO TO 2090

%**** ************************** ***** *************************

z***** coMPuTE ELECTRIC AND LT THERMAL OLIP1l’rS

%  ** ************************ ***** *************************

2051 EOUT=BETAV*SOLE *EFF 1* ( 1H2AMMA*EFF2*AIPHA 1 )

z**** ************************** ***** *************************

%***** cHEcK IF ALL ELECTRICITY CAN BE USED

Z*** ********** *•** * *** ********** **********•*** ***********  

XLAX-AMIN 1 ( PC SIZ/EFFPC , ( ESTORM-ESTOR ) / EEFF )

IF (EOUT. GT. EEE+QCl /COPE E+XLAX) GO TO 2095

Z** * **A’  ** * * ***** ******* ●   ** ** ***** **********•*********

%***** cycLE AND Go To NExT HouR

Z  ** *** ******** ************   ** ** *** *** *** **   ** ******

GO TO 900

%***   ** * *** ***** ******* * *** *** *************** *** ******  

z** *** FIx ENGINE cLIPPING CONDITION--HAVE T(I CHECK

%***** WHETHER REVISION AFFECTS MEETING THE THERMAL LOAD

z*** *** *** *** *•** *** k* ***** ********   A’** * ● *** *** ******* ****

2090 IF (QP. GT. ALptrA2*ENGMAx) GO TO 2091

BETAV= 1

GAMMA= 1

GO TO 2058

2091 IF (QP. GT. ENGMAX*(ALPHA 1+ALE’HA2) ) Go TO 2094

BETAV= 1

GAMMA= ( EN GMAX* (ALPHA 1+ALPHA2 ) -QP) / (ALPHA 1 *F NGMAX)

GO TO 2058

2094 GAMMA=O

BE TAV=ENGMAX/ ( ENGklAX* ( L-EFF 1 * (ALPHA 1+ALPHA2 ) ) +EFF 1 *Qp )

2058 CALL UPDATE (H~STM, HTQSTO, SOLE-ENGMAX/(EFF 1* BETAV), %

RES IDQ , EFFEX, EFFST , HTQST?l)

CALL UPDATE (LTQSTM, LTQSTO, -RESIDQ, RESID, EFFEX, EFFLOT, LTQSTM)

RESID9-RES ID9-RESID

SOL E=ENGFL4X/ (EFF 1 *BETAV )

GO TO 2051

z****************************************+*******************

%***** FIx overproduction oF ELEcTRIcllY IF HI FNEKCY

%***** CAN BE STORED; IF HT STORAGE FI’LL, CO BALK A?ir)

%***** SELL THE AV.41[,ABLE EL E(”TRICITI” TO THF GRID

I

●

2
HE SI” S. PB-PNL/L’LFO[)J 08/17/7h 1+:43:37

2

.

.

.

13.

1A.

15.

lb.

17.

lh.

15.

20.

;=* * * **************•** ******** *************   **  ********** ** *

GA-WA= 1

BETA\’= 1

Lx T(I 2111

2098 I F ( QP . LT . ( ALPHA 1 +A1. PHi12

L, A.’WA= ( L(ICT* ( ALPHA 1 +A1, PHA.? ) -(:P )

3LT\t’= 1

co ;,) J 11 J

‘? o~g [;lLwL\=o

*EOL’T ) LO Td 2099

(ALPHA 1 * (EOUT+F. FF”?*QP )

Bk LA\’ =Ed\’l / ( t.FF 1 *QP+Z.OCT* ( 1 -EFF 1 * ( ALPHA 1+ALI’HA2 ) ) )

.?11 3 C 11,1, 1 ‘i’DAT I ( tLT@STW, tiT05T0. S() LE. -EOCT/ Z

( 3F T\V*EFF 1 * ( 1 tGzLWA*ALiHA 1 *[FE’? ) ) ,P. FS I!)Q , EFFEX, t.FFST , HTQSTX)

S{1 Li, =Eol ” r / ( BET AL’*F, F F 1 * ( 1 K; M?’ A* AI.PHA 1 *EF F.? ) ) -RES IDQ

I E (R} S 13Q . LT. O ) LA) TU 2201

(:() -i(J 9[)[)

,,* ****** ********* ********* ***** ********* ************** *******

.***** cl{r[, K wirT~ k:[\ THE TH w-w. s pALL coxu I r LOX I?JG

,** ** * RL)LTE I j rHE .1OST EF” F IC I !:!iT

*********************** *********************** **************

.!100 IF (CO P,U. LT . EFF’ 1 * ( COF’r t.+ (ALPHA I+ALPHA2 ) *CUPAA) ) (X3 TO 2101

I F (SOLE. LT . QPwC / [;(1 PAA ) G() rC 2 Y [) 1

QP=QP+QL /Lo PAA

(JC 1 =0

cQL2=QL

T Q(; 2=0

UL=o

Go r(l 2 ?0 1

.2901 s(~[,r =SOLE.-(/P

IJp=(]

(/C=, j(--SOLF *COPAA

SO I r=o

(1) T() 2 J(11

.**** ******************* ************************* ************

‘=** *** c}i} [“K WHET} I CR THE B(Or TOllI SG cYLLE 1s MoRE F FF IL IENT

;7 ***** TH,\X THE TH i;&wL ROIJTE--I F THE BOTTOM I!JG CYCLE L S

7 ***** :[(IR F EFFr[- I k’!; r-- I . F, . LFF2*C0 PLE >CO PAA>O--GO To

~ ***** s iATEME\T 2501 ; (~THER~JI S E STAY llERE .

‘ *** * * ( SOTE : I r L\ AS SL” YED I \ THESE SK I ILHES

,*** * * TILiT t. h’F2 <’CFF 1 )

;** *** **   ** ************ ****** ************** ******* ********

:1OL IF ( CIO P.L\. LT . rFk’J*C(l Pr L 1 GU TO 2$01

(/(- 1=0 . ,](- 1 Ls s PA(. t. LL)K:) I r 10:, I \G L(),kc }[FT F Lhc TR 1(-ALLY

(< L2=QC : QC 2 LS S PAL Ii L()’<E IT L(IN 1 \L LO An WF,T THERMALLY

I F ( (J P+?C /(-OP.lA . GT . SULE* F.F E’ 1 *ALPHA? ) GO ?(1 2402

5LTAI’= 1

Gfci?4A= 1

G(1 i’) 2450

2!4 {02 IF ( Q P*2L 1 CLI PAA . GT . SULE. *F F F 1 * ( ALPI{A 1 +ALFI]A: ) ) ~;O r[l 2 LO ~

!3VA[’= 1

G$ CL\= ( SO LE*Ek’E” 1 * (ALPHA 1 +ALPtl,l 2 ) -Q P-Q9 /LOPAA ) / ( bLILF *1- t’! 1 * \LPHA ] )

G, ) T,> J+ 5n

2403 L F“ [ QP . CT. SO I F* EE’F 1 * ( ALPHA 1 +A1. F’HA: ) ) (;(1 : (~ ? ~()~

13FT .\ L’= 1

;,L f~~,l=o

(j(’ 1 =(< L-c(3PAA* ( >CILr *t F F 1 * ( A1, F’M 1 +A: PtJ.12 ) -~P )

qlL : =QC-Q(’ I

ml [() 2450

HESYS. PB-PNC/UGFO02 08/1 7/78 14: 43: 37

2153.

2154.

2155.

2156.

2151.

2158.

2159.

2160.

2161.

2162.

2163.

2164.

2165.

2166.

2167.

2168.

2169.

2170.

2171.

2~72 .

2173.

2174.

2175.

2176.

2177.

? 178.

2179.

2180.

2181.

2182.

2183.

2184.

2185.

2186.

2187.

2188.

2189.

2190.

2191,

2192.

2193.

2 19&.

2195.

2196.

2197.

2198.

2199.

2200.

2201.

2202.

2203.

~~04.

2205.

2206.

~~07 .

2208.

2209.

2210.

2211.

2212.

2404 GAMMA=O

BETAV- (SOLE-QP) / ( SOLE* ( 1-EFF 1 * (ALPHA 1+ALPRA2

QC2=0

QC1=QC

2450 IF (BETAV*SOLE*EFF 1. GT . ENGMAX) GO TO

) )

L05

2451 EOUT=BETAV*SOLE* EFF 1 * ( 1+GAMMA*ALPHA 1*CFF2 )

XLAX-AMIN~ (PCS IZ/EFFPC, ( ESTOFU4-ESTOR ) /EEFF)

LF ( EOUT . GT . EEE+XLAX+4~C 1 /COPEE ) GO TO 2410

GO TO 900

~**** ********************k****** ***** ************************

%***** FIX ENGINE CL1pp ING coNDITIoN--~vE ro CHECK

%***** WHETHER REvISION AFFECTS MEETIliG THE THERMAL LOAD

~  ** ************&*********** ● *****************************

2405 IF ( EliGELAX. LT . EEE+(QC-A)4AX1 ( (ALP%4 1+ALPHA2 ) *ENCMAX-QP ,0 ) %

*co P~) /CCIPEE ) GO TO 2705

QC 1=0

QC2-QC

IF (QPiQC/COPAA. GT .ALPHA2*ENGMAX) GO TO 2406

BETAV- 1

GAMMA=l

GO TO 2458

2406 IF (QP+QC/COP&i. GT . ENGMAX* (ALPHA 1+ALPHA2 ) ) GO TO ?LO 7

BETAV= 1

Gw= (ENGMAX* (ALPHA l+ALpHA2 ) -QP-QC /copMJ / fALpHAl *ENGMAX)

GO TO 2458

2407 IF (QP. GT. ENGMAX* (ALPHA 1+ALPHA2 ) ) co TO 2408

BETAV= 1

GAMMA=O

QC 1=QC-COPAA* ( ENGM.kX*(ALpHA 1+ALPHA2 ) -QP)

QC2=QC-QC 1

GO TO 2458

2408 GAMMA=O

BETAV=ENGMAX/ (ENGMAX* ( 1 -EFF1* (AI.PHA 1+ALPFL42 ) )

QC2=0

QC 1-QC

2458 CALL UPDATE (HTQSTM , HTQSTO , SL)LE-ENG!tAX/

RESIDQ, EFFEX, EFFST , HTQSTM )

EFF1 *QP )

BETAV*EFF ) , %

CALL UPDATE (LTQSTM, LTQSTO , –RESLDQ, RESID, EFFEX, EFFLOT, LTQSTFl)

RESID9=RESID9-RESID

SOLE= ENGMAW (BETA V*EFF1 )

GO TO 2451

Z**** ************************** ***** *************************

%***** F1x ovERpxoDUcT1oN OF ELECTRICITY LF HT ENERCy

%***** cAN BE STORED ; IF HT sTo~GE FUL, L, GO BACK AND

z***** sELL THE AVAILABLE ELECTR IC ITY TO THE cRID

Z  ** ************************* ***** ************************

2410 IF (HTQSTO. GE. HTQSTN*O . 99) GO TO 900

QC 1=0

QC2=QC

EOUT=EEE+XLAX

IF (QPUJC/COPAA. GT . ALFRA2*EOUT / ( l+ ALi’HAl*EFF 2) ) GO TO 241b

BETAV= 1

GAMMA= 1

GO TO 2468

2416 IF (QP+QC /COPM. GT . EOUT* (ALPHA 1+ALPHA2 ) ) GO TO 2417

BETAV= 1

GA..= ( EOUT* (ALPHA 1 +ALPHA2 ) -QP-QC /COPAA ) / (ALPHA 1 * Z

(EOUT+EFF2* (QP+QC/COPAA) ) )

2417 EOLJT=EEE+XLAXH) C/COPEE

IF ( QP. GT. EOL’T* (ALpHA 1 +ALPHA2 ) ) GO TO 2418

m’
HESys.pB-PNC/UGF002 o8/17/78 14:43:37

2213.

2?14.

2217.

221b.

:217.

2218.

2219.

2220.

2221 .

7,?. .. ‘.. .

22’2 3.

~~lfj -

2215.

2226.

2227.

2228.

2229.

2230.

2231.

2232.

2233.

2234-

2235.

~~36 .

2237.

2238.

~~39 .

~ ~ 40.

~ 241.

2242.

2243.

2244.

2245.

2246.

2247.

2~~8 .

2249.

2250.

2251.

2252.

2253.

2254.

2255.

2256.

2257.

2258.

2 ~ 59.

2260.

2261.

2262.

2’263 .

2264.

2265.

2266.

2261.

~~b$ .

2269.

2270.

2271.

2272.

BETAV= 1

Gm=o

EOUT. (COPEE*(EEE+XLAX )@ C+CjP*COPAA)/ %

( C13PEE~0PAA* (ALPHA 1 +ALPHA2 ) )

QC 1 =QC-COPAA* (Eo(IT* (ALPNA I+ALPHA2 ) -QP )

(&2 =QC-QC I

U] T,) jq~~

~~1 ~ GAM?lA=o

BETA V= EOUT/ ( EOUT* ( I -EFF L * (ALPHA 1 +ALPHA2 ) ) +EFF1 *QP )

QC2=0

Qc 1 =Qc

.2468 CALL UPDATE(HTQSTM,HTQSTO, SOLE-EOuT/ %

(BETAV*EFFl*( l+GiFlNA*ALPHAl*EFF2 )),RESIDQ,EFFEX,EFFST,HTQSTM)

SOLE.EOUT/ (BETAV*EFFl*( lffiAMMA*ALpHAl*EFF2))-RESIDq

IF (RESIDQ.LT.o) CO TO 2101

GO TO 900

~********************************+***************************

~************************************************************

%***** REAcH THIS SEcTION WNEN EFF2*C0pEE>c0pAA>0

%********************+***************************************

~*****%******************************************************

2501 Qcl=o

QC2=QC

IF (QP~c/cOp~.GT.S0LE*EFFI*ALpHA2 ) GO TO 2502

BETAV=~

cm=~

CO TO ~550

2502 IF (QP.GT.S0LE*EFFl*ALFHA2 ) GO TO 2703

BETAV=l

GAM!4A=1

QC1=QC=COP,U*(SULE*EFF1*ALPHA2-QP)

QC2=QC-QC]

GO TO 25j0

2503 IF (QF.GT.S)LE*EFF1*( ALPHA1+ALPHA2 )) Go To 2504

BETAV=I

GAMMA= (soLE*EFFl*(ALpHAI+ALp~2)-Qp) /(SOLE*EFFl*ALPHAl)

QCI=QC

QC2=0

GO TO 2550

2504 GAMMA=O

BETAV-(sOLE_Qp)/ (SOLE* (l-EFF1* (ALPHA1+ALPHA2) ))

QC1=QC

Qc>=o

2550 IF (BETAV*SOLE*EFF1 .GT.ENGMAX) GO TO 2590

2551 EOUT=BETAV*EFF1*SOLE* (1<AMMA*ALPHA1*EFF2)

XLAX=~INl (pcsIZ/EFFpc, (EsTO~-EsTOR)/EEFF)

IF (EOUT.GT.EEE+XLAX+QCl/COPEE ) GO TO 2595

GO T() 900

~*************************k**********************************

%***** FIX ENGINE CLIPPING CONDITION--HAVE TO CHECK

z***** WHETHER RFVISTON AFFECTS MEETING THE THERMAL LOAD

%************************************************************

2590 IF (ENGMAX.LT, EEE+(QC-AMAX1 ((ALPHA1+ALPHA2)*ENGMAX-QP, O) %

*COPAA)/COPEE) GO TO 2705

QC1=O

QC2=QC

IF (QP+QC/COPAA.GT.ALPHA2*ENGMAX) GO TO 2591

BETAV=l

Gm.1

GO TO 2558

HESYS.PB-PNC/UGFO02 08/17/78 L4:43:37

2273.

2274.

2275.

2~J6.

2277.

2278.

2279.

2280.

2281.

2282.

2283.

2284.

2285.

2286.

2287.

2288.

‘2~$9.

2290.

2291.

2292.

2293.

2294.

2295.

2296.

2297.

2298.

2299.

2300.

2301.

2302.

2303.

2304.

2305.

2306.

2307.

2308.

2309.

2310.

2311.

2312.

2313.

2314.

2315.

2316.

2317.

2318.

2319.

2320.

2321.

2322.

2323.

2324.

2325.

2326.

2327.

2328.

2329.

2330.

2331.

2332.

2591 IF (QP.GT.ALpHA2*ENGMAX) GO TO 2592

BETAV=l

GAMMA-1

QCl=QC-COPAA*(ALPHA2*ENcMAX-QP)

Qc~zcQc-Q~l

GO TO 2558

2592 IF (QP.GT. ENGMAX*(ALPHA1+ALPHA2) ) GO TO 2J93

BETAV-1

GAMMA-(ENGMAX*(ALPHA1+ALPHA2 )-QP)/(ALPHAl*ENG~x)

QC1=QC

Qc~=o

cc TO 2558

2593 GAMMA=O

BETAV=ENGMAX/(ENGMAX* (1-EFFl*(ALPHAl+ALpHA~ ))+EFF1*QP)

QC1=QC

Qc~=()

2558 CALL UPDATE (HT(&TM,HTQSTO, SOLE-ENGMAX/(BETAv*EFFl ), %

RESIDQ,EFFEX, EFFST,HTQSTM)

CALL LIPDATE(LTQSTM,LTQSTO, -RESIDQ,RESID,EFFEX,EFFLoT, LTQSTM)

RESID9-RESID9-RESID

SOLE-ENGMAX/ (BETAV*EFFl )

GO TO 2551

~************************************************************

z***** FIx ovERpRoDIJcTIoN OF ELECTRICITY IF HT ENERGY

%***** CAN BE STORED; IF HT sToRAGE FuLL, GO BACK AND

z***** SELL THE AvAIL~LE ELECTRICITY TO THE GRID

~************************************************************

2595 IF (HTQSTO.GE.HTQS~*O.99 ) Go To 900

EOLT-EEE+XLAX

QC1=O

QC2=QC

IF (QP+QC/COPAA-GT.ALpHA2*EouT/ (1+ALPHA1*EFF2)) GO TO 2596

BETAV=l

GAMMA=l

GO TO 2600

2596 EOUT=EEE+WtX+QC/COPEE

IF (QP.GT.ALPHA2*EOUT/(l+ALPHAl*EFF2) ) ~ To 2597

BETAV=l

GAMMA=l

EOUT-(COPEE*(EEE+XLAX)+QC+QP*COPAA) / %

(coPEE+(coPAA*ALPHA2)/( l+ALPHAl*EFF2 ))

Qcl-Qc-coPAA*(ALPHA2*EoL!T/ (l+ALPHA1*F.FF2)-QP)

QC2=QC-QC1

GO TO 2600

2597 IF (QP.GT.EOL!T* (ALPHA1+ALPHA2) ) GO TO 2598

BETAV-1

GAMMA-(EOUT*(ALPHA1+ALPHA2)-QP) /(ALPHA1* (EouT+EFF2*Qp) )

QC1-QC

QC2=0

GO TO 2600

2598 GAMMA-O

BETAV-EOUT/ (EOUT*(l-EFFl* (ALPHA1+ALPHA2) )+EFP1*QP)

QC1=QC

QC2=0

2600 CALL UPDATE(HTQSTM,HTQSTO, SOLE-EOUT/ %

(BETAV*EFF1*(1+GAMMA*ALPHA1*EFF2) ),REsIDQ.EFFEx.FFFsT,HTQs~)

SOLE=EOUT/(BETAV*EFFl* (1+GAMMA*ALPHA1*EFF2 ))-RESIDQ

IF (REsIDQ.LT.0) GO TO 2501

GO TO 900

~********************************************************k*** ●
HFSYS . PB-PNC/UCb’002 UX/ I 7 / 78 1 L : 

L 3 : 37

2333.

2334.

233s.

2336.

2337.

2338.

.!339 .

‘! 340.

2341.

:34~-

2343.

2344.

2345.

234h .

2347.

1348.

2349.

2350.

2351.

.2352.

2353.

2354.

2355.

235b.

2357.

z** ● •* usE T}{ F,wL ESLRGY TO ?lEETS PALE CON [) II 10::I <[>

;L*** ** L,),~L)–__TI{I s I s NOT TH }, ?!0S1 F F F 1(; IEST R(J[”TL B[’T Y[’S~

z***** BC I; SE, D AS l_ PIG [NE S I LE PRFVF. X 1 S TN! (J I’TI?’AI. R(l L’Tt> FROkl

Z**** * BE I Nc; TAKEK !

X**************** ****************** ******************* *******

2705 G.u-lMA=o

(JC 1 =AMAX1 ( EN G!<AX-EEE , 0 ) *COP EF

(/(- ‘!= QC-QC 1

SOLEG=ENGMAX* ( 1 / EI-’F 1- (ALPHA 1 +ALPHA2 ) ) +QP*JC2 /{. OFA.\

I F ( SOLEU . GL . SOLr ) (,0 TO 2710

FiEIAL’=ENGMAX/ ( Lk’F 1* SO1,EU )

CA1.1. UI’DATL (HTQSTM , HTQSTO , SOLE-SOLEU , RES IDQ, EFFEX , EFFST , HT05 I’Y )

LALL U PDATF ( LTQST?l , LTQSTO , -RFS I DQ , RES I D , !iFf EX , 1’F’l”LOT , LTQSTY )

RESII)9=REb ID9-RES 11)

S(JLE=SOLEL

G(o I-() 2551

2710 BIZTAV=ESGFIAX/ ( SOL E*EFF 1 )

QLJ= ( ( 1 -B EIAI’) *SO LL-QP+ (A1. F’PM 1+ALPHA2 ) *ESG?LIA ) *CUPAA

Qc 1= QC-QL2

GO TO 2551

.: ****** ********** ********** ************ ********** **********  

;: FI SD NAXI!4Lkl ENG ISE [CON D 11 ION S ,\\U ST ORAC} ?lAXIYlml S

Z** ******************* ************************ ****************

900 QOUT=SOLE* ( ( 1 -B ETAL’ ) +BE 1,\L’*EF F 1 * (.ALPtiA2+ALPHA 1 * ( 1 -GAMMA ) ) )

CAL1. UPDATE ( ESTOKM , ESTOR , EoL7-E}:L-QC1 /(;0 PEL , RES I Dl, , EFF PC , %

HE.S}’S . PB-PSC /UGFOO2 08/ 17/78 1 & : 4j : 37

2358.

2359.

2160.

2361 .

1362.

2363.

2364.

2365.

2366.

2367.

2368.

2369.

1370.

2371.

2372.

2373.

2374.

1375.

‘2376 .

?37 7.

2378.

2379.

2380.

2381.

2382.

EFFBAT , PCS I/! )

IF (COPAA. LT .0.1 ) CUPAA= 1.0

CAI,l, UPDATE ( LTQST?l, LTQSTO , QOUT-QP-I(~C 2*(0(” 2/co P,ti\ , RES ID(I , LF” FE>: , “{

EFFLOT , LTQSTYl )

RES LD9=Ril S ID9-REs I D(! E (K) =RES IDE

EY=GAMMA*ALPHA 1•EF F2

LZ=EOUT/ ( LFF 1 * ( 1+EY ) )

TENGM=.MAx 1 (TENGM, EZ*EFF1 )

BENGM=AYAX 1 (BENGM , EY*EZ*EFF 1 )

ENGM=AMAX1 ( ENGM , EOUT )

‘rOTTEO=TOTTEO+EZ *EFF 1

TOTB Eo=ToTBE(l+EY*Ez* EFF 1

TOTEO=TOTEO+EOUT

HTQ=HTQSTO-HTQSO

SHE=AMIN 1 (EZ , QSR )

HTQ9=0

IF (HTQ. LT. O ) l{ TQ9=-llT(j

STHF,=AlhI!; 1 (EZ-StlE ,HTQ9 )

FHET=O

SHET=SHET+SHE

STHET=STHET+STHE

6813 CONTINUE

RETURN

END

●
-qtiurR, RE. S 10[/, EFL.cx, EFFLLIT, LT(jsTY)

QHOL’R-RES IDQ-QP)

. . ******+*************** *********************** ***************

********************** *********************** ************* **

**** * HEAT EM: I NL SECT ION--VFRY CO?LFL Lb! 1’1:0 ! ! !

. ************************* ************************* **********

.,   ** **   **  ***************** ********** ****** ********** ● **

‘S OLE=Qs K+ti rq:>Tu

i , (/s1 ()=()

I F (CUFAA. r , i . f). O ~ ) (.O TC 98:9

I. EE=F F C+QC /L Oi’CL

(J( L 4.)(

(.)[-j =0

I (], 1 ~~

I]( =[1

(-() P l/- 1. II

5U2Y XLLI=A21Y 1 (PCS Iz /EFFPC, (E STOfLY-ES r[)R ) /EEFF )

XOtiT =,LVIN 1 (PCS IZ/EFFPC , ESTOR*EFFPC )

t’K=/WIIN 1 (EEE/ ( EFF 1 * ( 1+ALPHA 1 *EFF2 ) ) , QP+QC/COPM)

IF ( SOLE. CT . F,K) GO TO 2197

~ ( K I = ( EK-S()[. E ) / EFFE

;,lI.~.=~ ~:

157 Ik ( [“OPEL. L1 .0.01 \ w TO 2 I q~

HF SYS . PB-PNC /UGFO02 08/17/ 78 14 : 42 : ‘3 2

2033.

2034.

2035.

2036.

2037.

2038.

2039.

2040.

204 1 .

2042.

2043.

2044.

2045.

2046.

?047 .

2048.

2049.

2050.

2051.

2052.

2053.

205h .

2055.

2056.

2057.

2058.

2059.

2060.

2061.

2062.

2063.

2064.

2065.

2066.

2067.

2068.

2069.

2070.

2071.

2072.

2073.

207& .

2075.

2076.

2077.

2078.

2079.

2080.

2081.

2082.

2083.

2084.

2085.

2086.

2087.

2088.

2089.

2090.

2091.

2092.

Z**** *************************** ***** ************************

“g***** CHECK wHETHFR THE THERMAL SPAL’ r CON U I r ION I NC

z**** * ROL:T F, I S THE !.ius T EFF IC LFNT

Y********************* *********************** ****************

I F ( COPAA . L r . FFF 1 * ( C(IPEE+ ( ALPHA 1+ALPHA 2 ) *COPAA ) ) u.) ro 2!+[) 1

2199 QHOLR=QP+QC /CL)PAA

Qcl=o

~C2=QC

I F ( QHOIR . CT . ALPHA2*EFk’ 1 *SOLE ) CO TU : I () 1

BETAV= 1

GA..?lA= 1

GO TO 2109

2101 I F ( QHOLJR . CT . sOLE*EFF. 1 * (ALFH,t 1 +ALPHA 2 ) ) Go TO 2 10?

BETAV= 1

GAMMA= ( SOT. F*EFF 1* (ALPHA 1+ALPRA2 ) -QHOL’R) / ( SOLE*EFF 1 *ALPHA 1 )

GO TO 2109

2102 GAMMA=O

BETAV= ( SOLE-QHOUR ) / ( <OLE* ( 1 -EFF 1 * (ALPHA 1+AI.PHA? ) ) )

2109 IF (BETAV*sOLL*EFF 1. LT. ENGYAX ) GO TO 7090

9109 ECOLJT=BETAV*SOLE *EFF 1• ( 1 +.GA..*zlLPHA I *EFF2 )

IF ( EOUT . GT . EEE+XLAX ) GO TO 21 ?0

IF ( EOUT . LT . EEE-XOLJT ) GO TO 2130

GO TO 900

Z**** *************************** ***** ************************

%***** FIx LNG~NE cLIpp ING coNJ)ITION--~v}; TO L,HFCK

%***** ~ETHER REvIs ION AFFE~Ts MEF:TING THE THERMI, LOAD

z  ** ************************ ***** *************************

7090 IF (QHOUR. GT . ALPHA 2* ENGMAx) GO TO 5091

BETAV= 1

GAMMA= 1

GO TO 7058

5091 IF ( QHOuR. GT. ENcMAx* (ALpHA l+ALpHA2 ) ) Go T(> 7094

BETAV=l

GAMMA= (ENGFUX* (ALPHA 1+ALPHA2 ) -QHOLJR) / (ALPHA 1* F.NCMAX)

GO TO 7058

7094 GhW=O

BETAV=ENCMAX/ ( ENGMAX* ( 1 -F.FF1 * (ALPHA 1+ALPHA2 ) )+F.FF 1 *qHOUll )

7058 CALL UPDATE ( HTSSTM, HTSSTO , SOLE-ENGMAX/ ( EFF I *BETAV) , Z

RESIDQ , EFFEX, EFFST , HTSSTM)

SO LE=ENWAX/ (EFF1*BETAV)

GO TO 9109

Z**** *************************** ***** ************************

%***** Flx overproduction oF Electricity

Z  ** ************************ ***** *************************

21?() EOUT=EEE+XLAX

IF ( QHOUR . GT . ALPHAz*EOL’T / ( 1+ALPHA 1 *EFF2 ) ) GO TO ? 1‘? 1

BETAV=l

GAMMA= 1

GO TO 2129

2121 IF ( QHoUR. GT. EouT*(Ar.pw 1 +ALPHA2 ) ) GO TO 2 I 22

BETAV= 1

GmW= (EouT* (ALPHA 1+ALPHA2 )-QHOUR) / (ALPHA1* ( EO[JT+EFF2*QH011R ) )

GO TO 2129

2122 Gm=o

BETAV=EOUT/ (EOUT* ( I-EFF L * (ALPHA 1+ALPHA2 ) )+EFF 1 *QHOLJR )

2129 CALL UPDATE (HTQSTM, HTQSTO, SOLE-EOUT/ %

(BETAv*EFFl *( l+GLw*ALPHAl *EFF2 ) ) , R}:s IDQ, EFFLX, rFFsT, liTIQsTY )

CALL UPDATE (LTQSTM, LTqsTO, -RFS IDg, RFs ID, FFFFX, LFFLOT, [ Tf/s rv )

RESID9=RES ID9-RES ID

GO TO 900

●
tiFSYS. PB-PNC/UGFOO’2 08/17/78 14:42:52

2093.

2094.

2095.

2096.

2097.

2098.

2099.

2100.

2101.

2102.

2103.

?_ko& .

2105.

2106.

2107.

2108.

2109.

2L 10.

2111.

2112.

2113.

2114.

2115.

2116.

2117.

21 18.

2119.

2120.

~1~1 .

2122.

21?3.

? 124.

2125.

2126.

2127.

21’28.

2129.

2130.

2131.

2132.

2133.

2134.

2135.

‘2 136.

2137.

2138.

2139.

21 Lo .

2141.

2142.

‘2143 .

2146.

2145.

2 lbb .

2L47 .

2148.

2149.

2150-

2151.

2152.

z************************************************************

Z***** Flx ~~DERp~(jJ3~c’rIo~ OF Electricity_-~E~D n~c~,p!

-~************************************************************

2130 EOUT=EEE-XOUT

IF (QHOUR.GT .ALPHA2*ECIUT/ (I+ALPHA1*EFF2) ) GO TO 2131

‘3ETAV=1

GAM4A=1

GO TO 2139

2131 IF (QIi(JGR.GT .EOUT*(ALPHAl+ALPHA2) ) GO TO 2132

BEIAV=l

GA!LYA=(EOUT*(ALPHA1+ALPHA2) -QHOL’R) /(ALPHAl* (EOl!T+EFF2*QlIOUR ))

G{) T(.) ?139

~13~ GNIMA=O

BETAV-EOuT/ (EOUT*(l-EFFl* (ALPHA1+ALPHA2) )+EFF1*QHOUR)

2139 CALL UPDATE(tI’TSSTM,HTSSTO ,SOLE-EOUT/ Z

(BETAV*EFF1*( 1+GAMMA*ALPHA1*EFF2 )),RESIDQ,EFFEX,EFFST,HTSSTM)

E(K)=E(K)+RESIDQ/EFFB

GO TO 900

;:************************************************************

x***** CHECK wHETHER THE BOTTOMING CYCLE IS MORE EFFICIENT

2***** T~N THE THE~L RouTE--1F THE BoTToMING cycLE 1s

;O***** ,yoRE EFFIcIENT--I.E. EFF2*copEE,cop~Jo--Go TO

;***** sTATEMENT ~501; oT}lERwIsE sTAy HERE .

Z***** (NOTE: IT KS ASSUMED IN THESE SWITCHES

Z***** THAT EFF2<’iFFl)

;/************************************************************

2401 IF (COPAA.LT. EFF2*COPEF,) GO TO 2501

QC1=O / QCI IS SPACE CONDITIONING LOAD MET ELECTRICALLY

QC2=QC @ QC2 IS SPACE CONDITIONING LOAD MET THERMALLY

IF (QP+QC/COPAA.GT.SOLE*EFFl*ALPHA2 ) GO TO 2402

BETAV=I

Cm=l

GO TO 2450

2602 IF (QP+QC/COPAA.GT.SOLE*EFFl* (ALPRA1+ALPHA2)) GO TO 2403

BETAV=l

GAM!4A=( SOLE*EFF1* (ALPHAI+ALPHA2) -QP-QC/COPAA) /( SOLE*EFFl*ALPHAl )

GO TO 2450

2403 IF (QP.GT.SOLE*EFFI*(ALPHAl+ALPHAZ) ) GO TO 2404

PJETAV-1

GAM21A=0

QC1=QC-COPAA*(SOLE*EFF1* (ALPHA1+ALPRA2)-QP)

QC2=QC-QC1

GO TO 2&50

2404 GAMMA=O

BETAV=(SOLE-QP) /(SOLE* (1-EFF1*(ALPHAI+ALPHA2 )))

QC2=0

QC1=QC

2450 IF (BETAv*sOLE*EFF1 .GT.ENGMAX) GO TO 74o5

9450 EOUT=BETAV*SOLE*EFF 1*( l+GAMMA*ALPHA1*EFF’2)

IF (EOUT.GT .EEE+XLAX+QC l/COPEE) (X3 TO 2410

IF (EOuT. LT. EEE~cl/COpEE-XOuT ) GO TO 2420

GO TO 900

~************************************************************

z***** FIx ENGINE CLIPPING CONDITION--HAVE TO CHECK

z***** WHETHER REVISION AFFECTS MEETING THE THERMAL LOAD

z************************************************************

7405 QCI=O

QC2=QC

IF (QP+QC/COPAA.GT.ALPHA2*ENGMAX) Go To 7406

BETAV=I

RFSYS.PB-PNC/UGFO02 08/17/78 14:42:52

2153.

2154.

2155.

2156.

2157.

2158.

2159.

2160.

2161.

2162.

2163.

2164.

2165.

2166.

2167.

2168.

2169.

2170.

2171.

2172.

2173.

2174.

2175.

2176.

2177.

2178.

2179.

2180.

2181.

2182.

2183.

2184.

2185.

2186.

2187.

2188.

2189.

2190.

2191.

2192.

2193.

2194.

2195.

2196.

2197.

2198.

2199.

2200.

2201.

2202.

2203.

2204.

2205.

2206.

2207.

2208.

2209.

22L0.

2211.

2212.

GAMMA-1

GO TO 7458

7406 IF (QP+QC/COPAA.GT.ENGMAX*(ALPHAl+ALpHA2) ) GO TO 74o7

BETAV=l

GAMMA=(ENGMAx*(ALPHAl+ALPHA2)-QP-Qc/coPAA) /(ALPHAl*ENGMAX)

GO TO 7458

7407 IF (QP.GT.ENGMAX*(ALPHA1+ALPHA2 )) GO TO 7408

BETAV=l

GAMMA-O

QC1-QC<OPAA*(ENGMAX*(ALPHA1+ALPHA2)-QP)

QC2=QC-QC1

GO TO 7458

7408 GAMMA-O

BETAV=ENGMAX/(ENGMAX*( 1-EFF1*(ALPHA1+ALPHA2) )

QC2=0

QC1=QC

7458 CALL UPDATE(HTSSTM,HTSSTO, SOLE-ENGMAX/

RESIDQ,EFFEX,EFFST,HTSS’I?4)

SOLE=ENGMAX/(BETAV*EFFl )

GO TO 9450

EFF1*QP)

BETAV*EFF1), %

~************************************************************

Z***** FIX Overproduction OF ELECTRICITY

z************************************************************

2410 EOUT=EEE+XLAX

QC1-O

QC2=QC

IF (QpNC/cOpAi.GT.ALpibi2*EOUT/ (1+ALPHA1*EFF2)) GO TO 2416

BETAV=l

GAMMA=l

GO TO 2468

2416 IF (QP+QC/COPAA.GT.EOUT* (ALPHA1+ALPHA2)) GO TO 2417

BETAV=l

GAMMA=(EOUT*(ALPHA1+ALPHA2 )-QP-QC/COPAA) /(ALPHAl* %

(EouT+EFF2*(QP+Qc/coPAA) ))

GO TO 2468

2417 EOUT=EEE+XLAX+QC/COPEE

IF (QP.GT.EOUT*(ALPHA1+ALPHA2) ) GO TO 2418

BETAV=I

GAMMA-O

EOUT=(COPEE*(EEE+XLAX)+QC+QP*COPAA) / %

(COPEE+COPAA*(ALPHAI+ALPHA2’) )

QC1=QC-COPAA*(EOUT*(ALPHA1+ALPHA2)-QP)

QC2=QC-QC1

GO TO 2468

2418 GAMMA=O

BETAV=EOUT/ (EOUT*(l-EFFl* (ALpHAl+ALPHA2) )+EFFI*QP)

QC2=0

QC1=QC

2468 CALL UPDATE(HTQST?l,HTQSTO, SOLE-EOUT/ Z

(BETAV*EFFl*(ltGiMMA*ALPHAI*EFF2 )),RESIDQ,EFFEX,EFFST,HTQSTT4)

CALL UPDATE (LTQSTM,LTQSTO,-RESIDQ,RESID, EFFEX, EFFLOT,LTQSTM)

RESID9=RESID9-RESID

GO TO 900

z************************************************************

z***** FIX UNDERPRODUCTION OF ELECTRICITY--NEED BACKUP!

~******************************+*****************************

2420 EOUT=EEE-XOUT

QCl=O

QC2=QC

IF (QP+QC/COPAA.GT.ALPHA2*EOUT/ (I+ALPHA1*EFF2)) GO TO 2426
HFSYS. FB-PSC/UCFOg~ OP/ 17/7&l 14:42:52

BETAV= 1

GAMMA= 1

Go ‘To 2.18

~~ 26 IF (Q P+QC/COFAA .GT. EOL’T*(ALPHA l+ALPHA2) ) GO TO 24?7

BET AV= ~

GA.WMA=(EOUT* (AL PHAl+ALPHA 2)-Q P-QL”/COPAA) / (ALPHA1* %

( EOL’T+FFF.! * ( QP+QC /COJ’M ) ) )

GO TO 2478

2427 F. OUT= EEF-XOUI’+QC /COPEF

IF (QP. (, T. FOUT*(ALPHA 1+ALPHA2)) Go TO 2428

BETAV= 1

GAmlA=o

F. OUT=(COPEE *( EF. F-XOUT)flC~P*COPfi )/ %

(Cop EEWOPA-4* (ALpHAl+ALpHA2 ) )

QC 1 =QC-COPM* ( EOUT* ( AI.PHA 1+ALPHA2 ) -QP )

(JC 2 =Qc -Qc 1

GO TO 2478

1428 GAMMA=O

BET AV=EOUT / ( EOUT * ( 1 -EFF 1 * (ALPHA 1+ALPHA2 ) ) +EFF 1 *QP )

Qc 2 =0

(/(: 1 =Qc

2& 78 CALL (JPDATE(HTSSTM, HTSSTO, SOLE-EOUT/ %

(BETAV*EFF1*(1+GAMMA*ALPHA1*EFF2) ),RESIDQ,EFFEX.EFFST,HTSST?4)

E(K)=L. (K)+REsIDq/EFFB

GO TO 9oo

z************************************************************

~************************************************************

%***** REAcH THIS SECTION WHEN EFF2*cL)PEE>COPAA>0

%************************************************************

~************************************************************

2501 Qcl=o

QC2=QC

IF (QPflC/COP.AA.CT. SOLE*FFF 1*ALPHA2) GO TO 2502

BETAV=l

GAF04A=I

GO TO .2770

2502 IF (QP.CT. SOLE*EFFI*ALPHA2) GO TO 2503

BETAV*l

GAMMA-I

QCl=QC-COpAA*(SOLE*EFFI*ALPHA2~P)

Qc2=Qr-q(-l

GO TO J<50

2503 IF (QP.GT.SOLE*EFFl*(ALp~l+ALpM2) ) GO TO 250,

BETAV~l

GAMMA%(soLE*EFFl*(ALPHAl+ALPHA2 )-QP)/(SOLF*EFFl*ALPHA

QCl=Qc

QC2=0

GO TO 25S0

2504 GAMMA=O

BETAV=(SOLE-QP) /(SOLF* (1-EFF1*(ALPHA1+ALPHA2) ))

QCl=Q~

Qc~=O

2550 IF (BETAV*SOLE*EFFI .GT.ENGMAX) GO TO 7590

9550 EOUT=BETAV *EFFI*SOLE*( liGAMMA*ALPHAl*EFF2)

IF (EOUT.GT.EEE+XLAX~Cl/COPEE) GO TO 2595

IF (EOUT. LT. EEEi-QCl/COPEE-XOuT ) Go To 2590

GO TO 900

)

~************************************************************

% k FIX ENGINE CLIPPING (_of.JDITIoN-+A~ T(J CHECK

%,,** h WHETHER RJ7v1S10N AFFECTS MEETING THE THE~L LOAD

HFSYS.PB-PNC/UCF13@2 08/17/78 14:42:52

2273.

2276.

2275.

.?27b.

2277.

.?278.

2.?79.

~~~o.

2281.

2282.

2283.

2284.

2285.

?28b.

2287.

2288.

~~fJ9.

‘2~90.

2291.

2292.

2293.

2294.

2295.

2296.

2297.

2298.

2299.

2300.

2301.

2302.

2303.

2304.

2305.

2306.

2307.

2308.

2309.

2310.

2311.

2312.

2313.

2314.

2315.

2316.

2317.

2318.

2319.

2320.

2321.

2322.

2323.

2324.

2325.

2326.

2327.

2328.

2329.

2330.

2331.

2332.

:************************************************************

7590 QCI=O

QC2=QC

IF (QPw~c/coPAA.GT.A[.pHA2*FNG.wAX ~ GO ro 7591

BETAV=l

~~k~=l

Go I’L) 7558

7591 IF (QP.GT.ALPHA.?*ENGWAX) GO TO 7597

BETAV=l

GA?lMA=l

QL1=QC-COFAA* (ALPRA2*ENGMAX-QP)

QC2=QC-QC1

Go TO 7558

7597 IF (QP.CT. ENCMAX*(ALPHA I+ALPHA?)) LO T() 75Y3

BETAV=l

GAMMA=(ENGMAX*(ALPHA1+ALFHA2 )-QP)/(ALPHAl*E?iG!iAX)

QC1=QC

QC2=0

CO TO 7558

7593 GAMMA=O

BETAV=ENGMAX/ (ENGMAX* (1-EFF1*(ALPHA1+AI.PHA2 ))+FFFI*QP)

QC1=QC

QC2=0

7558 CALL UPDATF(HTSSTM,HTSSTO ,SOLF-ENGMAX/ (BETAV*EFFl ~, %

RESIDQ, EFFEX,EFFST,HTSST!-1)

SOLF.=ENGMAX/ (BETAV*EFFl )

GO ro 9550

~*************************************************+********** %***** FIX ov~RpRoDLJcTIoN OF ELE~TRIcIr~

z********************************************

2595 EOUT=EEE+XLAX

QC1=O

QC2=QC

IF (Qp+Qc/c0Pk4.GT.ALpHA2*E0uT/ (l+ALpHAl*EFF2

BETAV=l

GAMMA=l

GO TO 2600

2596 EOUT=EEE+XLAX+Q( ICOPEE

***************

) GO TO 2596

IF (QP.GT.ALPHA2*EO~T/( 1+ALPHA1*EFF2)) GO TO 2597

BETAV=l

GAKMA=l

EOUT=(COPEE*(EEE+XLAX)qCiqP*COPAA )/ %

(COPEE+(COPAA*ALpHA2)/ (1+ALFHAI*EFF2) )

QCl=QC-COPAA*(ALPHA2*EOUT/ (l+Al,PtlAl*EFF2)-QP)

QC2=QL-QCI

GO TO 2600

2597 IF (QP.GT.EOUT*(ALPHA1+ALPHA2 )) GO TO 2598

BETAV=l

GAMMA=(EOUT*(ALPHA1+ALPHA2)-QP) /(ALPHAl*(EOUT+EFF2*QP) )

QC1=QC

QC2=0

GO TO 2600

2598 GAMMA=O

BETAV=EOUT/(EOUT*(l-EFF1*(ALPHAl+ALPHA2 ))+EFF1*QP)

QC1=QC

QC2=0

2600 CALL UPDATE(HTQSTM, HTQSTCI, SOLE-EOL’T/ Z

(BETAV*EFF1*( l+WMMA*ALPHA 1*EFF?) ),RESIDQ, FFFEX,EFFST, HTQ5TYj

CALL UPDATE(LTQST’M, LTQSTO, -RESIDQ,RFSID, hFFFX,EFFLt)T. I.TQSTM)

RESID9=RESID9-RESID

.

.

7

m

03
l[FSYS. PB-PSC/rGF’002 08/17 /7Z’ 14:42 :5.I HFSYS. PB-PNC/UGFO02 08117178 14:42:52

●

2333.

.2334.

.? 335.

.2336.

2337.

2338. ? ~J9 .

2340. ? 341. 2 342 .

.!343 .

.! J44 .

.!365 .

.2 3’ib .

2347.

234s -

.? 349.

2350.

2351. 2 35? .

‘?35 3.

2354.

2355.

23 >b .

:357 .

2358.

2359.

23bo .

2361.

2362.

2363.

2364.

2365.

2! 3 b b .

2 ~h 7.

2368.

2369.

2370.

2371.

23 7.?.

co T{) 900

;:************************************************************

***** FIX [’\L)EKp Rt}ll[ ~.li{j~ (1F L[Fc TRL(. IT}’ -–NLED BA(-KL’P!

.  ** ***************** *7%******************* ****************

z5~o P.[)L’T–F [. F,-XLIL T

Qc 1 =0

(]C 2=(JL

I F ( QP+QL /C[3 F’I’u\ . [.T . .A1 PH.AJ*F! 1[’ : ‘ ( 1 +ALf’HA 1 *EF F: ) ) GO T(1 2696

BF,’1 AV=1

LAHMA= 1

G[) TO 2601

2696 EOCT=F.r E’-XOL’T+QL /CO P~’t,

I E’ ( QP . CT . ALPHA 2 * E.(~L’T / ( 1 +A!. PH,\ 1 *EFF

2 ) ) C.(J TO 2597

BETA\’= 1

L}L’f!iA= 1

EIIL’I= ( COPEE* ( F ;’F -XOL’T ) +QL+2P *( L) PAA ) / ~

( LOPE E+(LUPAA*ALPHA2 ) / ( 1 +ALPHA 1*EFF2 ) )

(~(-I =Q~_(-(O PAA* ( A], PHA 2* FO[’T / ( 1 +A1.1’HA1 *FFF’2 ) -LIP )

Qr 2 =Qc-fj(”1

Gt) TO 2601

2b97 1 ~“ ( QP.C 1. EIJ1’T* (ALP1!A 1 +ALPHA? ) ) Go L’(I ?698

BFTA~r=1

GitlMA= ( LOL’T* ( ALPHA 1+ALPHA2 ) -(JP ) / (ALPHA 1 * ( EOI’T+EFF2*QL’ ) )

(JC 1 =Qr

(/c 2=0

GO T(J ?501

2698 GA.Y!!=O

BETA’v’=EOUT/ ( LOUT* (

[<L 1 =Qc

Qc~=o

-EFF 1 * ( ALPHA 1+ALPHA2 ) ) +EFF *QP )

2601 CALL Li P1)ATE (HTSSTY, HTSST(J, SO LE-EOL’T / “’

( BETA tl*kFF 1 * ( 1 +GA!!LMA*ALPIIA 1 *EFFJ ) ) , RES IL)Q , EFFEX , EFFST , HTSST!I )

E(K) =E (K )+RESIDQ/ FFFB

GO TO 900

;:**   **  *** * ***** ** ** * ****** * ‘h ************ ******** * ******** * **

x FIND M.AXI?4U?1 rh(, Lh

E Ct)NilIT 10’J S AND STORAGE ‘l,LYIML’MS

;>******** ********** ********** ********** ********** *********** **

900 SO1. E= EL)UT / ( BLTAV* k:h’F

1 * ( 1 +CAHNA*ALPHA 1 *RF F2 ) )

QOL

-T=SOLE* ( ( 1 -B ETA\’ )+ BETA V*EFF I* ( ALPHA I+ALPHA I * ( 1-GIM4MA ) ) )

IF ( CO PEE . LT. 

C .1 ) CO PFE=l .0

?373.

.! 374.

?3 75-

237b.

2377.

i373.

2379.

‘?jxo.

2381.

2382.

2383.

2384.

2385.

2386.

1J87.

238X.

2389.

2190.

.? 391.

2392.

2393.

2394.

2395.

2396.

2397.

2398.

2399.

2400.

2401.

2402.

2403.

2404.

2405.

2406.

2407.

2408.

2409.

2410.

2411.

2412.

2413.

CALL L’PDATE ( EST[)L~l , ES 10R , EIOl:T-EEE-11/C 1 *QC 1 /L,OPEE , 

Z

RES IDL , EFFPC , EFFBA’1 , PCS IZ )

IF ( CtlPAA. LT .0.1 ) COFAA=l .0

LALL ICPDATC ( LTQST?!, LTQST() , QOL’T-QP-QC 2/ LOPAA, RE.S IDQ , %

EFFEX , EFFLIOT , LTQSTY )

KES ID9=Rr.S LD9-RF,S LDQ

rY=G~mA*ALPHA1 *EFFz

!. Z= EOL’T/ ( EFE” 1 * ( 1 +LY ) )

TEhLM=AXAXl (T FNCr?l, E7, *EFF 1 )

BLNG?t=AMAXl ( BE!iGM , EY*EZ*EFF 1 )

rNGH=~’mxi ( rx[;!l, EO LIT )

TOT rEU=TOTTEtO+EZ*EFF 1

TOTB EO=TOTB EO+EY*EZ *EFF 1

‘TOT EO=TOTEO+L.OUT

LBM=L4AXi ( FBM, E(K ) *EFFB-Lz )

CALL (’ l’DATE ( HTQSTM , HTQSTO , HTSSTO , RE~ TDQ , EFFLX, EFFST, HTQST!4 )

CALL 

U PDATF ( L rQST?l , LTQST(), -RES IDQ, R ~ . i J , E’Ft’ LX, EFFLoT , LTQSTN )

RES ID9=RES ID9-RES I D

HTSSTO=O

HT(/=HTQSTO-HTQSC

FHE=AMIN 1 (E (K) *EFFB , EZ )

EBEM=AMAX1 (EBEM, FHE )

SHE=AMIN 1 (EZ-FHE , QSR )

HTQ9=0

IF (HTQ. LT . O) HTQ9=-HTQ

STHE=AMINL (EZ-FHE-SHE , HTQ9 )

FHET=FHET+FHE

SHET=SHET+SHE

STHET=STHET+STHE

IF (E (K) . LE . . IE-9 ) GO TO 6813

DELTA=QP l-AMAXl (O, LTQSO-LTQSTO ) -AMAX

IF (DELTA. LE .0 ) G() TO 6814

FFHW=DELTA/FHWEFF

6814 IF ( EFFB*E (K ) . LT . EZ ) GO TO 68 E (K)=E (K)+Ez* ( 1 /EFFBE-l /EFFB )

(%3 TO 6811

6812

E (K) =E (K ) *EFFB/EFFBE

6811 FULL= FUEL+E (K)

6813 CONTINUE

RETURN

END

(O, -HTQ)
1.

?.

~.

4.

5.

h .

7.

8.

Y.

10.

11.

12.

1000.

1001.

1002.

1003.

1004.

1005.

1006.

1007.

1008.

100’3 .

1010.

10 I 1.

1012.

1013.

101+.

2000.

“ P ROG!VJ4 NAME : HWSYS . JB

“: JoHh C . BULL

“. ENrRGY PROGRAM

;: uFF” L{ E OF TF,CHN(OLUGY ASSLs SHF, NT

“, COHF’1 LED

DATE : 12/ 19/77

T [ME: 12: 59: 7

‘: F’RIJGRM HWSYS . JB F(3R RLINN I SC SOLAR IIOT WATER SYSTUIS

AND COKVENTIONA1 SYSTEMS WITH }-I. ECTR IC BAC’KI’F’

:. c)R ELEc ~R IC ANI) FOSSIL b’~’r 1 BAC KI’P .

●
PVSYS. PB-PNC/UGFO02 08/17/78 14:42:21

1.

2.

3.

4.

5.

6.

7.

8.

9.

10.

11.

12.

1000.

1001.

1002.

1003.

1004.

1005.

1006.

1oo7.

1008.

1009.

1010.

1o11.

1012.

1013.

1014.

2000.

2001.

2002.

2003.

2004.

2005.

2006.

2007.

2008.

2009.

2010.

2011.

2012.

2013.

2014.

2015.

2016.

2017.

2018.

2019.

2020.

2021.

2022.

2023.

2024.

2025.

2026.

2027.

2028.

2029.

2030.

2031.

2032.

% PROGRAY NAME: PVSYS.JB

% JOHN C. BELL

% ENERGY PROGRAM

% OFFICE OF TECHNOLOGY ASSESSMENT

% COMPILED

z DATE: l/12/78

% TIME: 13: 6:43

% PROGRA.. PVSYS.JB FOR RUNNING PHOTOVOLTAIC SYSTEMS WITH

z ELECTRICITY, FOSSIL FUEL, OR BoTH FOR BACKUP

z

k

z

SUBROUTINE SYSTEM(K,QSH)

DIMENSION E(8760),HWLOAD( 168)

IMPLICIT REAL(L)

COMMON/AXXX/COPA,EHWEFF,HCOPM,CCOPH, EFFB,ENGMAX,EFF1,EFF2,ALPHA1 ,2

ALPHA2, HTQST?!,LTHTS, HTHTS, LTQSTM, LTLTS,HTLTS, HLHTH,Z

FHWEFF,HLLTH,EFFBE, ESTOPJW,EFFBAT,PCSIZ, EFFPC,HEATMX,%

COOLMX, FAN,TL,TH,XXX, NHTQ,NLTQ, IGRID, IsoLAR, IA, ISMTH, Z

IHR,IOFFPK

COMllON/CXXX/COPAA,COPEE, EBM,EBEM, EEE,EFFEx,TENGM, BENGM,ENGM, %

ESR, ESTOR,EEFF,FFHW,FHET ,FUEL,HTSSTM,HTQ,HTQI, HTQO, .%

HTQSO,HTQSTO,LTQI,LTQO ,LTQSO, LTQSTO,QA,QC,QC 1,QC2, %

QC2Z,QE,QP,QS,QSR,RESID9, SHET, STHET,TOTTEO,TOTBEO, %

TOTEO,HLHTL,HLLTL, EFFLOT,EFFST, IPRINT

COMMON/XDATA/E,HWLOAD

DATA IPRINT/1/

QC1=O

QC2=0

QHOUR=QP

IF (COPAA.LE.O.OO1) GO TO 32

QHOUR=QP+QC/COPAA

32 CALL UPDATE(LTQSTM,LTQSTO,QSR-QHOUR, RESIDQ,EFFEX,EFFLOT,LTQST’M)

IF (RESIDQ.LT.0) RESID9=RESID9-RESIDQ

xTEMP=AMAX1 (O,QP-(QHOUR-RESIDQ) )

IF (XTEMP.LE.O.OO1 ) QC=AMAX1(O,QC-COPAA*(QHOLI-AMAX1 (O,RESIDQ)-QP) )

QP-XTEMP

IF (QSH.GT.0) Qc2z=QsH-Qc

IF (QSH.LE.0) QC2Z--QSH-QC

~*************************************************************

Z PHOTOVOLTAIC CALCULATIONS

~*************************************************************

ESR=ESR*EFFPC

XTEMP=AMIN1 (ESR,EEE)

ESR=ESR-XTlllP

EEE=EEE-XTEMP

IF (IGRID.EQ.0) GO TO 550

IF (IGRID.EQ.3) GO TO 570

XTEMP=AMINl (ESR,QC/COPEE)

ESR=ESR-XTEMP

QC=QC-XTEMP*COPEl?

XTEMP=AMLNl (ESR,QP/EHWEFF)

ESR=ESR-XTEMP

QP=QP-EHWEFF*XTEMP

CALL UPDATE (ES~ORM, ESTOR,ESR/ (EFFPC**2)-~/COPEE-QP/EHWEFF-EEE , %

RESIDE, EFFPC, EFFBAT,PCSIZ )

E(K)=RESIDE

IF (RESIDE.LT.0) E(K)=RESIDE*EFFPC

QC1-QC

GO TO 900

PVSYS.PB-PNC/UGFO02 08/17/78 14:42:21

2033.

2034.

2035.

2036.

2037.

2038.

2039.

2040.

2041.

2042.

2043.

20&4.

2045.

2046.

2047.

2048.

1049.

2050.

2051.

2052.

2053.

2054.

2055.

2056.

2057.

2058.

2059.

2060.

2061.

2062.

2063.

2064.

2065.

2066.

2067.

2068.

2069.

2070.

2071.

2072.

2073.

2074.

2075.

2076.

2077.

2078.

2079.

2080.

2081.

2082.

2083.

2084.

‘2085.

2086.

2087.

2088.

2089.

2090.

2091.

209’2.

570 IF (COPEE.LT.O.001) GO TO 571

QC1=QC

XTEMP=A?lINl( QC/COPEE,ESR )

FSR=ESR-XTEMP

QC=QC-COPEE*XTEMP

CALL rPDATE(ESTORY, ESTOR,ESR/ (EFFPC**2)-QC/COPEE-EEE,RESIDE, %

EFFPC, EFFBAT,PCSIZ)

E(K)=RF.SIL)E

I F (REsIDE.LT.0) E(K)=RE510E*EFFPc

FFHW=QP/FHWEFF

FIJEL-FUEL+FFHW

GO TO 900

571 CALL UpDATE(ESTORM, ESTOR,ESR/ (EFFPc**2)-EEE,REsIDE, EFFPC, %

EFFBAT,PCSIZ)

E(K)=RESIDE

IF (REsIDE.LT.0) E(K)=RESIDE*EFFPC

FFHW=QP/FHWEFF

QA=QC/(COPAA*EFFB)

FUEL=FL!EL+QA+FFHW

EBM=AMAX~(EBM,QA*EFFB)

Qc~=Qc

CC TO 900

550 IF (COPEE.LT.O.001) GO TO 555

QCS=QC

XTEMP=AMINl (QC/COPEE, ESR)

ESR=ESR-XTEMP

QC=QC-COPEE*XTEMP

CALL UPDATE(ESTORll,ESTOR, ESR/(EFFPC**2)-Qc/cOpEE-EEE,RESIDE, %

EFFPC, EFFBAT,PCSIZ)

QC1=QCS

IF (REsIDE.LE.0) GO TO 5 5 9

XTEMP=AMAXl (O, RESIDE-QC/COFEE)

IF (XTF.MP.LT.O. 0001) QC=RESIDE*COPEE

QC1=QCS-QC

EEE=XTEMP

GO TO 672

555 CALL UPDATE(ESTORM, ESTOR,ESR/ (EFFPC**2)-EEF,,RESIDE, EFFPC, Z

EFFBAT,PCSIZ)

IF (RESIDE.LE.0) GO TO 558

EEE=RESIfiE

GO TO 672

559 QC=O

558 EEE=O

XTEMP=AMINI (QP,-RESIDE*EHWEFF)

QP=QP-XTEMP

RESIDE=RESIDE+XTEMP/EHWEFF

CALL UPDATE (LTQSTM,LTQSTO, -RESIDE ,RESIDQ, EFFEX,EFFLOT,LTQSTM)

RESID9=RESID9-RESIDQ

E(K)=RESIDE

672 FFHW=O

IF (COPAA.GT.O.001) GO TO 673

EEF=EEE+QC/COPEE

COPAA=I

QC1=QC1+QC

QC=O

673 IF (ALPHAZ*EEE.GE.~/COPAA@P) GO TO 6722

IF (COPEE.GT.(3 .1) GO TO 6721

6719 X=QP-ALPHA2*EEE

IF (X.LT.0) GO TO 6728

FFHW=X/FHWEFF

2

m

g
FVS”iS. PB-PNC/UCFO02 08/17/78 14:4? :21

2093.

2094.

‘?095 .

JO Yb .

2097-

2098.

.? 099.

2100.

2101.

2102.

2103.

2104.

2105.

2106.

2107.

2108.

2109.

2110.

2111.

2112.

2113.

QA=FFHW+(QC/COpM ) /EFFB

CA] TLO b7z7

b728 QA=(QC/COFAA+X)/’EFFLi

b727 Qs=o

GO TO b7J3

h722 QA=o

Qs=A1,p}~J*EE~ -Ql’-lJC /LOPAA

6723 QF=FFF/1’FFI

QC.2=QC

co ro 6730

67: 1 1 F ( l-Fh 1 * ( CO PEE+Al, PHA2*COPAA ) . LE . CO L’AA*EFFB ) CO TO h7 J ‘

IF ( AI.PHA J* ( F FE+t~(- / (:o PLF, ) . LT . Qp ) GO r(l 6 7,? 5

QA=O

QE=(EEE+ ~~!p~( /CtILJAA-ALPHAZ *EEE ) / (ALPHA 2+cOPEF/COPAA) ) /E~’F 1

QS=O

QC 1=QC 1+C(OPEE* ( EL’”F 1 *QE-EEF: )

QC2=QC-(jC 1

GO TO 6730

6725 QE= (EEE+QC/COPEE) /EFF1

QA=(QP-ALPHA2* (EEE~c /COPEE ) ) /FHwEFF

FFHW=QA

P\’SYS . PB-PNC /~’GFOO 2 08/ 17 / 78 14 : 42 : 21

2114.

2115.

2116.

2117.

2118.

2119.

2120.

?121.

2122.

?123.

2124.

2125.

2126.

2127.

2128.

2129.

2130.

2131.

2132.

: 133.

QS=O

QC 1=QC 1+QC

6730 FUEL= FUEL+QA+QE/ EFFBE

CALL UPDATE (LTQSTM, LTQSTO , QS , RLS IDQ , E~’FFX , El E“LoT , LTQST?I )

RF,S ID9=RES ID9-RES LL)Q

EZ=QE*EFF 1

TEN(24=AMAX1 (TF.NGM , EZ )

EN(24=TENGM

TOTTEO=TOTTEO+EZ

TOTEO=TOTTEII

EBM=~xl ( EBM, (QA-FFHW) *F.FFB )

EBEM=AMAX1 (EBEM, QE )

GO TO 900

;******************** ********************** ********************

z FIND ?4AXIM[M ENG INF c13NDI rIo Ns AND STORAGE MAx IYLXS

Z  ** ******************** *************** ********************

900 C(INT INUL

IF ( 10FFPK . EQ .1 ) CALL IIFFPK1 (K> Qt’ , Qc , QsH, C(lpEE , EHKLFF )

RETURN

ENLL

●
C(3LI l. PB-PXC/lTCFOO,l 08/17/78 14:46:07

1.

?.

3.

4.

3.

6.

7.

8.

9.

10.

11.

l?.

13.

.?000 .

?00 1 .

2 [)0 2.

2003.

2004.

2005.

2006.

2007.

2008.

‘2 D 09.

201 n .

’20 11 .

’201 2.

201 j .

2014.

2015.

2016.

2017.

2() 1 x .

2019.

2 (0.! 0.

202 I .

20’.?2.

2023.

:0 ’24 .

2025 .

2026.

2027.

2028.

2029.

2030.

2031.

2032.

2033.

.!034 .

2035.

2036.

.2037.

2038.

2039.

2040.

L04 1.

2042.

2043.

‘204&.

2045.

204b .

Z I’ROGRA!! NA.?IE: CL)LL 1. JB

“. JOHN L . BELL

Z ENERGY PROGRAM

t oFF LC E OF Tt:CHNOLOGk’ ASSESSMENT

;: COMP 1 LED

7 DATt. : 11/ 30/77

z TIME : 1 : 18: 6

% PRuGRAM COI.L 1. JB FOR RUNNING FLAT PLATE COLLECTORS AND

% TWO DIMENSIONAL TRACKING COLLECTORS WITH

~,,. ELECIRIC AND THERMAL OUTPUT

;:

. . SI’BROUTINF LOLL (I SYS1)

DIMENSION DAYLEN( 365) ,sONOON( 365) ,DECL( 365)

DIXENS1ON RADJ)N (8760) ,RADTH (8760)

DI!41XSION EQ(4), A(4) ,B(&)

IMPLICIT REAL(L)

COMMON /B X,XX/CRATIO , TRANS , AREAC , LAT , LONG , LONGST , TILT , AZ , XKE, BETA, 2

CELLEF , ELECAB , FC , ULOSS , COVERN , FR , ALPHA , FLOUR ,DENS , CP , %

ABC, ABD,APWID,COLEN,FOCLEN, COSPAC,RIMANG,REFLEC,CELLL, %

ALPHAV,YYY(5) ,ISYS, IFLOW,IEW,IYYY(5)

DIMENSIoN SCEL(37), ISCEL(8)

rQL’IVALENCE (SCEL(l),CRATIO) ,(ISCEL(l),ISYS)

DATA A,B/-.23,34197,732265E65E 1,-.9O3E-1,O. ,-.7351E1,-.939uE1,-. 3661/

PIE2=6.2831853

PIFV=360/(PIE2)

READ(24) DECL

REWIND 25

RE.AO(25) RADDN,RADDN,RADDN,RADTH

READ(12,*,PRLNPT=’FILE IWMBER FOR COLLECTOR COEFFICIENTS: ‘) IF

IF (IF.LE.0) GO TO 1110

REWIND IF

RF.AD(lF) SCEL,ISCEL

1120 READ(12, 99, PRoMPT=’LIsT/cHANGE VARIABLES AND VALUES: ‘) ITST

99 FOKMAT(A4)

IF (ITSr.EQ.’YES’) GO TO 1123

IF (ITST.EQ. ‘NO’) GO TO 1124

IF (IT5T.EQ.’soN’) Go TO llLo

GO TO 1120

1123 WRITE(13,900) CRATIO,TRANS,AREAC,LAT ,LONG,LONGST,TILT, Z

AZ,XKE,BETA,CELLEF, ELECAB,FC,ULOSS,COVERN ,)%

FR,ALPHA,FLOWR>DENS ,CP

WRITE(13,qOl) ISYS,TFLOW

900 E. ORMAT(’ REAL NU?IBERS ‘/%

,

#“,4x, ’vALuE’ ,4X,’DEFINITI ON”/Z

,

1 ’ ,lPE10.3,’

,

2,, IPEI0.3, ’

,

3 ’ ,1PE10.3, ”

, ~, ,1FE10.3, ’

,

5 ’ ,lPEIO.3,’

.

6’, IPrlo.3, ”

1 ’ ,LPE1O.3,’

.

8’, 1PE10.3, ’

,

9’, IPEIO.3,’

‘ 10 ‘, 1PE10.3, ’

’11’ ,1PE1O.3,’

‘ 1’? ‘ ,1PE10.3, ’

‘13’ , IPEIO.3,”

‘14’ , 1PE10.3, ’

:CONCENTRATION RATIO (DIM)’/’Z

:OPTICAL EFFICIENCY OR TRANSMISS. (.LE. l.OO) ’/%

:COLLECTOR AREA (M**2)’/%

:LATITUDE (DEG)’/%

:LONCITUDE (DEG)’ /’Z

:STANJ)ARD LONGITUDE (DEG)’/Z

:COLLECTOR TILT ABOVE HORIZONTAL (DEG)’/’Z

:COLLF,CTOR ANGLE WRT SOUTH (DEG)’/%

:COLLECTOR HEAT REMOVAL FACTOR (KW/(M**2*C))’ /%

:CELL TEMI’ COEFF (1/DEG CENT)’/Z

:CF.LL EFFIc O 28C (.LE. l.00)’/%

:CEJ.L ABSORPTIVITY (.LE. l.00)’/Z

:FRAC OF RECEIVER COVERED WITH CELLS (.LE. l.00)’/%

:THERMAL LOSS COEFF (KW/?l**2*C)’/Z

COLL1.PB-F’NC/UGFO02 08/17/78 14:46:07

2047.

2048.

2049.

2050.

2051.

2052.

2053.

2054.

2055.

2056.

2057.

2058.

2059.

2060.

2061.

2062.

2063.

2064.

2065.

2066.

2067.

2068.

2069.

2070.

2071.

2072.

2073.

2074.

2075.

2076.

2077.

2078.

2079.

2080.

2081.

2082.

2083.

2084.

2085.

2086.

2087.

2088.

2089.

2090.

2091.

2092.

2093.

2094.

2095.

2096.

2097.

2098.

2099.

2100.

2101.

2102.

2103.

2104.

2105.

2106.

‘ 15’, IPEI0.3, ’ :NUMBER OF GLASS COVERS (DI!4)’/7O

‘ 16 ‘ ,1PE10.3, ” :COLLECTOR HEAT REMOVAL FACTOR (.LE. l.00)’/X

‘ 17’, 1PE10.3, ’ :A8soRB OF THERMAL- ONLY SURFACES (.LE. I.00)’/z

‘ 18 ‘ ,1PE1O.3,’ :FLOW RATE (CM**3/SEC*M**2)’ /%

‘ 19 ‘, 1PE10.3, ’ :FLUID DENSITY (GM/CM**3)’/%

‘ 20 ‘, 1PE1O.3,’ :FLUID SPEC. HEAT (CAL/GM*C)’)

901 FORMAT(’ INTEGERS ‘1%

,

#’,hx,’vALuE’ ,4X,’DEFINITION’ /z

,

1 ’ ,16,4X, ’ :OUTPUT--ELEC(1 ), ELEC & THERMAL(2), THERMAL(3) ”/Z

,

2 ’ ,16,4x,’ :CONST FLOW RATE(l), CONST OUTPUT TEMP(2)’)

1124 REAI)(12, *,PROMPT=’VAR # A!!D VARIABLE: ‘) IV,V

IF (lV.L’i.0) GO TO 1125

IF (lV.GT.37) GO TO 1124

SCEJ,(IV)=V

GO TO 1124

1125 READ(12, *,PROMPT=’VAR // AND IVARIABLE: ‘) IV,I

IF (IV.LE.0) GO TO 1126

IF (IV.GT.8) GO TO 1125

ISCEL(IV)=I

GO TO 1125

1126 READ(12,*,PROMPT=’FILE NUMBER TO STORE COLLECTOR COEFF: “) IV

IF (IV.LE.0) GO TO 1140

REWIND IV

WRITE(IV) SCEL,ISCEL

w

k

z COMPUTE RISETIME AND SETTING TIME OF SUN AND SOLAR ANGLES

x

1140 LAT=LAT/PIEV

TILT=TILT/PIEV

AZ=AZ/PIEV

ISYS1=ISYS

SINLAT-SIN(LAT)

COSLAT=COS(LAT)

TANLAT=TAN(LAT)

SINTLT=SIN(TILT)

COSTLT=COS(TILT)

SINAZ=SIN(AZ)

COSAZ=COS(AZ)

AREACR=AREAC/CRATIO

XFLASSF=0.004186*FLOWR*CP*DENS*CRATI0

ALPHAV-FC*ELECAB+( l-FC )*ALPHA

DO 50 1=1,365,1

DO 2500 J=1,4

EQ(J)zA(J)*cos((p1~2* (J-1)*1)/365.25)+B(J)*sT~ ((pIE~*(J_l)*l)/365.25 )

2500 CONTINUE

RISANG=ACOS ((-TANLAT)*TAN(DECL (I)))

DAYLEN( I)=PIEv*RIsA!!G/7 .5

SONOON( I)=13.5-((EQ( 1)+EQ(2)+EQ(3)+EQ(4)+4* (LoNGsT-LoNG) )/60)

50 CONTIHUE

IF (IFLow.NE.1) FR=l

RETURN

A

% HOURLY COMPUTATION BEGINS

“.

z

ENTRY COLLO1(K,TFIN,TFOUT,TA,QSR, ESR)

IF (RADTH(K).LE.0) GO TO 38

IF (RADJ)N (K)+RAJJTH(K).LE. 0.0001) GO TO 38

TAIR=TA-273

I=(K-1)/24

J=K-24*(1)
27.

28.

29.

30.

31.

3.! .

33.

3* .

35.

35.

37.

38.

JL 39.

1=1+1

rll=J-O .5- SO\LKl\ ( I J +DAI”LE:: ( 1 ) ‘ .?

I r ( ( T1) . LT . ()) . OR . ( TU .(: r . OA}’LE\ ( 1 ) ) ) GO TO 38

RI SAN(; =A( (I\ ( ( -TAN I AT) *TA!! (L)LC L ( I ) ) )

I F ( CRAT I L) . L 1’ .1. > ) CL) TO b 1

RADT(OT=T” ANS *RALIDN ( K ) *C RAT 10

T t ( L SYS . F(J . 1 ) co 1’0 2 : i

(,( ) 10 ‘ , ‘ . . .

b 1 HRM\G= ( bLINOCIN ( I ) -1 ) *RI SANG/ (DAYLEN ( T ) / 2 )

5 I NDEL = s [ Y (DLC [. ( I ) )

Los Dr( =cos (LIFCL ( I ) )

COSRRA=COS ( HRANG)

C 1 =S LNI)h;C* S1 NLAT

C ?= U3SL)EC*COSLAT* COSHRA

LOSTI{ r=C I +C z

IF (r[OSTHE. LE. O) GO TO 38

C05 INC=C I*cos,TLT-s INDEC*cOs LAT*s INTLT*c(]sAZ+ %

r; Z*C,JSTLT+ .

,“

C05DEC* SINLAT*SINTL,T* COsAZ*cOsH~+ .,0

CO SDF,C*SINTLT*SINAZ *SIN ( HRANG )

Cos INC=A!!X1 (o, COSINC )

RADDIF=A?lAxl ( ( ( RADTH (K) -RADDN (K

+RADTH ( K) * ( 1 -COSTLT ) / 10,0 )

I F ( T SYS . EQ. I ) Go To 223

IF ( COVERN .GE .1.5 ) GO TO ’221

R,\ DTOT=TRANs*RADDN (K)* ( CO SINC* *

G(I T[l 222

*C OS THE ) * ( 1 +cos TLT ) / ~ ) %

J ? 1 MD IOT.TRANS*RADDN ( K) * ( CL)S L SC ** 1

.7) --- IF” ( IFLOW. EQ .1 ) GO To 225

TTEMP= (T FIN+TFOUT ) / z

DE?io!l= 1- ( FC*RADTOT*CEL) ] F*BF 1’ I-L’ L(ISS

Lo ru 226

.?25 TTEFfP=TFIN

.25 ) +RADU I F*O. 89* TRkVS

5 ) +F.Al)o I F*o. 80* TRAINs

/.xKk

DENOM= 1 -FR*FC*BET i.* L”ELLF b’*RAL)TOT* ( 1 /XKF+O . 5/ KMASSF)

~~~ AT EMPo=RADT(I : * I AL PHA;’-FC*CELLEF* ( 1 -BETA* (TTE!!-28 ) ) )

t/SR=AMAXl ( FR*AR t ACR* ( ,}r E!4P0-UI.OSS* (TTEMP-TAIR ) ) /DENOM, o)

Ik” ( ( I FLOW . E(J .2 1. J.~;D . (Al E24P0-[T1.0 $ S* (TFOITT-TAIR ) . LE .0 ) ) QsR=O .

I F ( I SYS . NE .2 ) G(1 T(7 321

IF ( IFLOW. FII .21 i ( F LL=TTE!.fPfiSR/ ( XKE*ARFIACR )

IF ( IF LOLJ. F, 1. I I i (< ELL=TFIN~SR* ( o. 5/wss F+l /XKE ) /AREACR

ESR=ARFL\, , * ~ *R,~ToT*cELLEF* ( l-BETA* (TCELL-2X ) )

GO TO 3 J I

~ 23 RADT , –~~)DN (K) *COS INC+RAD1)IF

COLL 1. P!3-P!4C /UGFOO? 08/ 17 /78 14 : 46: 07

: 150.

:151.

2 L52 .

.? 153.

.21 5’i.

2155.

21 5b.

.!157.

2158.

.!1 59.

? 160.

.! 161.

? 162 .

21h 3.

21 hb .

.2165.

21h6.

? 167.

2168.

? 169.

2170.

2171.

2172.

2173.

2174.

2175.

2176.

2177.

2178.

2179.

2180.

2181.

2182.

2183.

2184.

2185.

2186.

2187.

2188.

2189.

2190.

2191.

2192.

J :4 [<SR=O

kTLWLK=AREAC R* RADTC)’r *FC*LELLFF* ( 1 -BETA* (l,\ IR+AL1’HA\’*M)TL~T /XKF-2R ) )

‘L SR=XNLklFR/ ( l–CEl.lEF*BETA* RADr O r/XKE )

j z 1 I F ( QSR . LF . [) ) QSR=O .

IF (ESR. LE.0) ESR=O.

RETL’RN

38 QSR=O

EsR=()

RETURN

z

z oL~TPUT STATF.MLNT S

ENTR}’ COLLO 2

IF ( I SY5 . EQ . I ) GC TO 17

I F ( I FLOW. EQ . ,? ) GO TO 17

17 IF (CRATIU . GT .1.5 ) h’R [TF ( 13, 454)

454 F(JRMAT ( ‘ TWO-AX1 S TKACKI NG SYSTEM ‘ )

IF ( CRAT TO . LT .1.1 ) WRLTE( 13, &50)

450 FORMAT ( ‘ FLAT PLATE COLLECTOR’ )

IF ( ISYS . EQ .1 ) WRITE ( 13,451 )

451 FoRMAT ( 1X, ‘ PASSIVE ELECTRIC-ONLY COLLEC I’OR’ )

IF ( ISYS . EQ .2 ) WRITE ( 13> 45?)

452 FORMAT ( 1X, ‘ COMB INF.D THERMAL AND ELEC ~RIC COLLECTOR’ )

IF ( ISYS . EQ. 3 ) WRITE ( 13,45))

453 FORMAT ( 1X, ‘THL’XLMAI,-ONLY CO1.LECTOR ‘ )

IF( IFLOW. EQ. 1 ) WRITE(13, 455)

455 FORMAT ( ‘ CONSTANT FLOW RATE’ )

IF(IFLOW. EQ. 2) WRITE( 13,456)

456 FORMAT ( ‘ CONSTANT OUTPUT TF.MPERATURZ’ )

RETURN

z

79 OUTPUT SUMMARY

z

ENTRY COLL03

LAT=LAT*P IEV

AZ= AZ*P I EV

T L LT=TILT*PIEV

WRITE ( 13. 900) CRAT IO, TRANS , AREAC , LAT , LONG , LONGST , TI LT , %

AZ, XKE , BETA , CELLEF , EL ECAB , FC , ULOS S , COVERN , 2

FR , ALPHA , FLOWR , DENS , CP

wRlrE( 13,901) ISYS, TFLOW

RETURN

END

●
COLL?. PB-P!iC/UGF002 08/17/78 14:47:14

1.

7. .

3.

4.

5.

b.

7.

8.

9.

10.

11.

12.

13.

2000.

2001.

2002.

2003.

2004.

2005.

2006.

2007.

2008.

2009.

2010.

‘2011.

2012.

2013.

2014.

2015.

2016.

72017.

2018.

2019.

zo~o.

‘20.?.1.

20~’2.

20~3.

2024.

2025.

20~6.

2027.

2028.

2029.

.2030.

2031.

2032.

2033.

2034.

2035.

2036.

2037.

2038.

2039.

2040.

2041.

2042.

2043.

2044.

2045.

2046.

Z PROGRA.. NA!YE: COLL2.JB

Z JIJH\ C. BELL

Z EN LRGY PROGRAM

% OFFICE OF TECHNOLOGY ASSESSMENT

Z. COMPILED

YJ. DATE.: 1/ 4/78

.,. . TIME: 23:51:24

% PROGRAM COLL2.JB FOR RUNNING ONE-DIMENSIONAL

~: COLLECTORS k’IrH THERMAL AND ELECTRIC

%

&

SUBROUTINE COLL(ISYS1)

DI!lENSION DAYLEN(365), SONOON(365 ),DECL(365)

DLVESSION RADDN(8760),RADTH(8760)

DIYCNSION EQ(4),A(4),B(4)

IYPLICIT REAL(L)

co~D:oN/Bxxx/cRATIo ,Tp~Ns,~E*c,LAT,LoNG, LoNGsT,

TRACKING

OUTPUT

U1,L2,XKE.BETA,%

CCLLEF,ELECAB,FC,ULOSS ,COVERN,FR,ALE’HA,FLOUR,DENS ,CP,%

TO,T1,APWID,COI,EN, FOCLEN,COSPAC ,RIMANG,REFLEC,CELLL, %

ALPHAV,YYY(5) ,IsYs, IFLow, lEh’,IYYY(5)

D1!4ENS1ON SCEL(37),ISCEL(8)

Equivalence (SCEL(l),CRATIO) ,(ISCEL(I),ISYS)

DATA A,B/-.23,34197,732265E65E 1,-.903E-1,0. ,-. 7351E1,-. 93912E1,-.366I /

PIE2=6.’2831853

PIEV=360/(PIE2)

READ(2L) DECL

REIJIVD 25

READ(25) RADDN,RADL)N,RADDN,RAI)TH

READ(12,*,PROMPT=’ FILE NUMBER FOR COLLECTOR COEFFICIENTS: “) IF

IF (IF.LE.0) GO TO 1120

REWIND IF

READ(IF) SCEL,ISCEL

1120 READ(12, 99,PROMPT=’ LIST/CHANGE VARLABLES AND VALUES: ‘) ITST

99 FORMAT(A4)

IF (ITST.EQ.’YES’) GO TO 1123

IF (ITST.F,Q.’NO’) GO TO 1124

IF (ITST.EQ. ’NON’) GO TO 1140

GO TO 1120

1123 WRITE(13,900) CRATIO,TRANS,AREAC,LAT ,LONG,LONGST,U1,%

U2,XICE,BETA,CELLEF,ELECAB,FC ,%

ALPHA,FLOh’R,DENS,CP, TO,T1,APWID,COLEN, Z

FOCLEN,COSPAC,RIMANG, REFLEC,CELLL

WRITF.(13,901) ISYS,IFLOW,LEW

900

,

FORMAT(’ REAL NUMBERS—’1~

#’,4X,’VALUE- ,4X,’DefinitiOn ’/Z

, 1’, 1PE10.3, ’

,

2 ‘,1PE1O.3,’

.

3’, 1PE1O.3,’

, ~. ,1PE1O.3,’

.

5 ’ ,1PE1O.3,”

,

b’, 1PE10.3, ’

,

7’, 1PE10.3, ’

.

8’, 1PE1O.3,’

,

9’, 1PE1O.3,’

‘ 10 ‘, 1PE10.3, ’

‘11’ , 1PE1O.3,’

‘ 12 ‘, 1PE10.3, ’

‘ 13 ‘,1PE1O.3,’

:CONCENTRATION RATIO (DIM)’/Z

:OPTICAL EFFICIENCY OR TRANSMISS. (.LE.l.00)’/X

:COLLECTOR AREA (M**2)’/%

:LATITUDE (DEG)’/Z

:LONGITUDE (DEG) ’/Z

:STANDARD LONGITUDE (DEG) ’/Z

:U1--THERMAL LOSS COEFF PARAMETER (KW/(M**2*C) )’/%

:u2-.THE~L Loss coEFF p~ETER (~/(M**2*c))Z/%

:CELL HEAT REMOVAL FACTOR (KW/C*M**2)’/%

:CELL TEMP COEFF (1/DEG CENT)’/%

:CELL EFFIC fi 28C (.LE. l.00)’/%

:CEL1, ABSORPTIVITY (.LE. l.00)’/%

:FRAC OF CELL AREA COVERED wITH CELLS (.LE. l.00)’/%

COLL2. PB-PNCJUGFO02 08/17/78 14:47:14

2047.

2048.

2049.

2050.

2051.

2052.

2053.

2054.

2055.

2056,

2057,

2058,

2059.

2060.

2061.

2062.

2063.

2064.

2065.

2066.

2067.

2068.

2069.

2070.

2071.

2072.

2073.

2074.

2075.

2076.

2077.

2078.

2079.

2080.

2081.

2082.

2083.

2084.

2085.

2086.

2087.

2088.

2089.

2090.

2091.

2092.

2093.

2094.

2095.

2096.

2097.

2098.

2099.

2100.

2101.

2102.

2103.

2104.

2105.

2106.

‘ 17 ‘ ,1PE1O.3,’ :ABSORP OF

‘ 18’ ,1PE10.3, ’ :FLOW R4TE

THERMAL-ONLY SURFACES

(~**3/sEc*M**2). IZ

(.LE. l.00)’/%

‘ 19 ‘, 1PE1O.3,’ :FLUID DENSITY (GM/CM**3);;Z’ -

‘ 20 ‘ ,1PE1O.3,’ :FLUID SPEC. HEAT (cAL/GM-c)’/z

‘ 21 ‘ ,IPE10.3, ’ :TO--THERMAL COEFF TEMPERATURES (DEG CENT)’/Z

‘ 22 ‘, IPEIO.3,’ :T1--THERMAL cOEFF TEMPERATURES (DEG CENT)’/Z

‘ 23 ‘ ,lPEIO.3,’ :COLLECTOR WIDTH(M)’/Z

“ 24 ‘, 1PE10.3, ’ :COLLECTOR LENGTH(M)’/%

‘ 25 ‘ ,1PE1O.3,” :FOCAL LENGTH (H)’/%

‘ 26 ‘ ,1PE1O.3,’ :CENTER TO CENTER SPACING OF COLLECTORS(M)”/%

‘ 27 ‘ ,1PE1O.3,’ :RLM ANGLE--EDGE-FP-CENTER (DEG)’/Z

“ 28 ‘ ,1PE10.3, ’ :OPTICAL REFLECTIVITY (.LE. I.00)’/z

‘ 29 ‘, IPE~O.3,’ :CELL LENGTH (M)’)

901 FORMAT(’ INTEGERS

,

‘/%

#’,hX, ’VALLTE’ ,4X, ”DEFINITION’/X

, 1’ ,16,4X, ’ :OUTPUT--ELEC(1 ), ELEC & THERMAL(2), THERMAL(3)’/Z

,

2 “ ,16,4X, ’ :CONST FLOW RATE(l), CONST OUTPUT TEMP(2) ’/%

,

3 ’ ,16,bX,’ :EAST-WEST AXIS(l), NORTH-SOUTH POLAR AxIs(2)’)

1124 READ(12,*,PROMPT-’ VAR # AND VARIABLE: ‘) IV,V

IF (IV.LE.0) GO TO 1125

IF (IV.GT.37) GO TO 1124

SCEL(IV)=V

GO TO 1124

1125 READ(12,*,PROMPT=’VAR # AND IVARIABLE: ‘) IV,I

IF (IV.LE.0) GO TO 1126

IF (IV.GT.8) ~ TO 11Z5

ISCEL(IV)=I

GO TO 1125

1126 READ(12,*,PROMPT=’FILE NUMBER TO STORE COLLECTOR COEFF: “) IV

IF (IV.LE.0) GO TO 1140

REWIND IV

WRITE(IV) SCEL,ISCEL

z

z COMPUTE RISETIME AND SETTING TIME OF SUN AND SOLAR ANGLES

.%

1140 ISYS1=ISYS

LAT-LAT/PIEV

RIMANG=RIMANG/PIEv

TANLAT=TAN(LAT)

SINRIM=SIN(RIMANG)

COSRIM-COS(RIMANG)

DO 50 1=1,365,1

DO 2500 J-1,4

EQ(J)=A(J)*COS ((PIEZ*(J-1 )*1)/ 365.25)+B(J)*sIN( (PIE2*(J-1 )*1)/365.25)

2500 CONTINUE

RISANG=ACOS( (-TANLAT)*TAN (DECL(I)))

DAYLEN(I )=PIEv*RIsANG/ 7.5

SONOON(I )=13. 5-((EQ(l)+EQ( 2)+EQ(3)+EQ(4)+4*(LoNGsT-LoNG ))/60)

50 CONTINUE

Ull=U1/CRATIO

U22=U2/CRATIO

XMLNV=l/ (.008372*FLOWR*CP*DENs*cUTIo)

AREACR=AREAC/CRATIO

RP.R=cELLL/cOLEN

RETURN

z

% DAILY COMPUTATION BEGINS

k

ENTRY COLLO1(K,TFLN,TFOUT,TA,QSR,ESR)

IF ((RADTH(K) .LE.0).oR. (RADDN(K).LE.0)) GO TO 38
_ COLL2. PB-PNC/UGFOOJ 08/17/78 14:47:14

:

2107.

2108.

-. 2109.

2110.

2111.

21 12.

2113.

2114.

2115.

2116.

2117.

2118.

2119.

2120.

2121.

2122.

2123.

2124.

2125.

2126.

2127.

2128.

2129.

2130.

2131.

2132.

2133.

2 13L .

2135.

2136.

2137.

2138.

2139.

2140.

2141.

2142.

2143.

2144.

2145.

2146.

2147.

2148.

2149.

2150.

2L51 .

2152.

2153.

2154.

2155.

2156.

2157.

2158.

2159.

2160.

2161.

2162.

TAIR=TA-27 3

I= (K-l)/24

J-K-24*(I)

1=1+1

TD=J-o.5-soNooN( I)+DA~LEN (1)/2

IF ((TD.LT. 0) .OR. (TD.GT.DA~EN (I))) ~ To 38

COSINC=COS (DECL(I))

RLSANG=ACOS ((-TANLAT) *TAN(DECL(I)))

HRANG=( SONOON(I )-J)*RISANG/ (DAYLEN(l)/2)

IF(IEW.EQ. l)GO TO 350

GO TO 360

350 COSINC-( 1-((COSINC) **Z)*((SIN(HRANG) )**2))**0.5

%

% COMPUTE SHADING

z

PHI-LAT-ATAN( (TAN(DECL(I )))*(l. /COS(HRANG)))

THE=ACOS(COSINC)

GO TO 370

360 IF(ABs(HRANG) .GT.PIE2/4)G0 TO 38

PHI=HRANG

THE=DECL(I)

370 SRAD1=AIYIN1(l ,COSPAC*ABS (COS(PHI))/APwID)

RADIUS=( 2*FOCLEN)/(1 .KOSRIM)

SHAD2=FOCLEN+( ((RAoLus*SINRIM)**2) /(12*F0CLEN))

SHAD2=AMAX1 (0, 1-( (SHAD2*ABS (TAN(THE) ))/COLEN))

SHADTO=SHAD1*SHAD2

L

% COMPUTE THERMAL LOSSES

z

TRANSM-TRANS*(COSINC**O. 25)

FCIONO=O

IF (SHAD2.GE.(RRR/2)+.5) %

FCIONO=(CRATIO/COLEN)*CELLL*REFLEC*TRANSM*SHADl* %

CELLEF*FC*RADDN(K)*COSINC

762 IF ((sHAD2-.5)*COLEN.GE.CELLL/2) Z

ALPHIO=(CRATIO/COLEN)*REFLEC*SHADl*TlUNSM*RADDN(K)%

*COSINC*(ALPW*(Sw2*COLEN-FC*CELLL)+(Fc*ELEc~*cELLL) )

IF ((sHAD2-o.5)*coLEN.LT.-cELLL/2) %

ALPHIO=CRATIO*REFLEC*TRANSM*RADDN(K) %

*COSINC*ALPHA*SHADTO

IF (~S((SHAD2-.5)*C0LEN) .LE.cELLL/2) z

ALPHIO.(CRATIO/COLEN)*REFLEc*TRANsM*RADDN (K)* %

cosINc*(ALPHA*( (coLEN-Fc*cELLL) /2)+ z

Fc*ELEcAg*( (sHAD2-O. 5)*coLEN+CELLL/2) )*SHADl

IF(ISYS.EQ.l)GO TO 7bl

TTEMP=TFIN

IF(IFLOW.EQ. 2)TTEMP=(TFIN+TFOUT )/2

QLl=ALPHIO-FCTONO*(l-BETA*(TTEMP-28) )

IF(IFLow.EQ.l)Go To 763

u’

~ CALCULATE ouTpuT FoR SYsTEM wITH FIxED ouTpuT TEMpERAT~E

z

IF(TTEMP-TAIR.GE.TI-TO) %

QL2=ull*cMTIo*(Tl-To)+u22*cMTIo*(TTEMP-TAIR-(Tl-To) )

IF(TTEMP-TAIR.LT.T1-TO) %

QL2=ull*cRATIo*(TTE~-TAIR)

COLL2.PB-PNC/UGFO02 08/17/78 14:47:14

2163.

2164.

2165.

2166.

2167.

2168.

2169.

2170.

2171.

2172.

2173.

2L74.

2175.

2176.

2177.

2178.

2179.

2180.

2181.

2182.

2183.

2184.

2185.

2186.

2187.

2188.

2189.

2190.

2191.

2192.

2193.

2194.

2195.

2196.

2197.

2198.

2199.

2200.

2201.

2202.

2203.

2204.

2205.

2206.

2207.

2208.

2209.

2210.

2211.

2212.

2213.

2214.

2215.

2216.

QSR=AREACR*(QL1-QL2)/( l-FCIONO*BETA/XKE)

CO TO 764

z

Z CALCULATE OUTPUT FOR FIXED FLOW RATE

z

763 QL2=ull*cMTIo*(Tl-To)+u22*cRATIo*(TTmP-TAIR-(Tl-To) )

QSR=AREACR*(QL1-QL2)/(l+U22*XMINV-FCIONO*BETA* (1/XKE+XMINV/CRATIO))

TTEMP=TFIN+QSR*XMINV/AREAC

IF(TTEMP-TAIR.LT.T1-TO) .%

QSR=AREACR*(QL1-U1 l*CRATIO*(TFIN-TAIR) )/(l+Ul l*XMINV-FCIONOZ

*BETA*( l/XKE+XMINV/CRATIO) )

TTEMP=TFIN+QSR*XMINV/AREAC

764 ESR=AREACR*FCIONO*( l-BETA* (TTEMP+QSR/ (XKE*AREACR) -28))

GO TO 766

761 QSR-O

ESR=AREACR*FCIONO*( l-BETA*(TAIR-28+ALPHI0/XKE ))/(l-FCIONO*BETA/ (XKE*FC ))

766 QSR--AMAX1(O,QSR)

ESR=AMAX1(O,ESR)

RETURN

38 QSR-O.

ESR-O.

RETURN

.%

% OUTPUT STATEMENTS

.

;NTRy coLLo2

IF (IEW.EQ.1) WRITE(13,1132)

1132 FORMAT(’ EAST-WEST AXIS TRACKING COLLECTOR’)

IF (lEW.NE.1) WRITE(13,459)

459 FORMAT(’ ONE-AXIS POLAR NORTH-SOUTH TRACKING COLLECTOR’)

IF(ISYS.EQ.1) WRITE(13,451)

451 FORMAT(lX, ’PASSIVE ELECTRIC-ONLY COLLECTOR’)

IF(ISYS.EQ.2) WRITE(13,452)

452 FORMAT( lX,’COMBINED THERMAL AND ELECTRIC COLLECTOR’)

IF(ISYS.EQ.3) WRITE(13,453)

453 FORMAT( lX,’THERMAL-ONLY COLLECTOR’)

IF(IFLOW.EQ.1) WRITE(13,455)

455 FORMAT(’ CONSTANT FLOW RATE’)

IF(IFLOW.EQ.2) WRITE(13,456)

456 FORMAT(’ CONSTANT OUTPUT TEMPERATURE’)

RETURN

z

Z OUTpUT SUMMARY

z

ENTRY COLL03

LAT=LAT*PIEv

RIMANG=RIMANG*PIEV

WRITE(13,900) CRATIO,TRANS,AREAC,LAT,LONG,LONGST,U1 ,%

U2,XKE,BETA,CELLEF,ELECAB,FC ,%

ALPHA,FLoWR,DENS,CP,TO,T1 ,APWID,COLEN,%

FOCLEN,COSPAC,RIMANG,REFLEC,CELLL

WR1TE(13,901) ISYS,IFLoW,IEW

RETURN

END

●
COLL3. PB-PNC/UGFO02 08/17/78 14:48:14

1.

2.

3.

4.

5.

6.

7.

8.

9.

10.

11.

1.2.

13.

2000.

2001.

2002.

2003.

2004.

2005.

2006.

2007.

2008.

2009.

2010.

2011.

2012.

2013.

2014.

2015.

2016.

2017.

2018.

2019.

2020.

2021.

2022.

2023.

2024.

2025.

2026.

2027.

2028.

2029.

2030.

2031.

2032.

2033.

2034.

2035.

2036.

2037.

2038.

2039.

2040.

204L.

206,2.

2043.

2044.

2045.

z

%

%

%

%

z

%

%

z

%

%

x

%

PROGRAM NAME: COLL3.JB

JOHN C. BELL

ENERGY PROGRAM

OFFICE OF TECHNOLOGY

COMPILED

DATE: 12/29/77

TIME: 12:29:42

PROGRAM COLL3.JB FOR

WITH THERMAL

ASSESSMENT

RUNNING HELIOSTAT FIELDS

OUTPUT ONLY

SUBROUTINE COLL(ISYSI)

DIMENSION DAYLEN(365),SONOON(365) ,DECL(365)

DLYENSION RADDN(8760),RADTH(8760)

DIMENSION EQ(4),A(4)>B(4)

IMPLICIT REAL(L)

COMMON/BXXX/CRATIO,TRANS ,AREAC,LAT,LONG,LONGST,TILT,AZ ,XKE,BETA,%

CELLEF,ELECAB,FC,ULOSS,COVERN,FR,ALPm,FLOWR,DENS,CP, %

ABC,ABD,APWID,C OLEN,FOCLEN ,COSPAC .RIMANG.REFLEC ,CELLL,%

ALPHAV,YYY(5),ISYS,IFLOW, IEW,IYYY(5)

DIMENSION SCEL(37),ISCEL(8)

EqUiValenCe (scEL(l),cRATIO) ,(IscEL(l),IsYs)

DATA A,B/-.2E-3, .4197,-.32265E l,-.903E-l,0. ,- .7351E1,-. 93912E1,-.3661 /

DIMENSION GAMMA(3, 7),DAYTIM(3, 7),NzDAY(365)

DATA GAMMAf.92,.56,0. ,.92, .58, 0., .92, .6fj,0. , .91,.72,0.,.87,.7,0. ,.82,

.58,0. ,. 78, .49,0./

DATA DAYTIM/ 1.7,5.36,7. 18,1.7,5.1,6.96, 1.7,3.93,6.56, 1.48,3.6,6.03, 1.51,

3.48,5.57,1.74,3.6,5.17 ,1.39,3.6,4.781

DATA NZDAY/4*7, 31*6,30*5,31*4, 30*3,31*2,29*1,31*2,30*3, 31*4,30*5,31*6,26*7/

PIE2=6.2831853

PIEV-360/(PIE2)

READ(24) DECL

REWIND 25

READ(25) RADDN,RADDN,RADDN,RADTH

READ(12,*,PROMPT=’FILE NUMBER FOR COLLECTOR COEFFICIENTS: ‘) IF

IF (IF.LE.0) GO TO 1120

REWIND IF

READ(IF) SCEL,ISCEL

1120 READ(12,99,PROMPT=’LIST/CHANGE VARIABLES AND VALUES: ‘) ITST

99 FORMAT(A4)

IF (ITST.EQ. ’YES’) GO To 1123

IF (ITST.EQ.’NO’) GO TO 1124

IF (ITST.EQ. ’NON’) GO TO 1140

GO TO 1120

1123 WRITE(13,900) CRATIO,AREAC,LAT,LONG,LONGST,ULOSS, %

ALPHA,REFLEC

900

.

FORMAT(’ REAL NUMBERS—’1~

#’,4X,’vALUE’ ,4X,’DefinitiOn ’/Z

, 1’ ,1PE1O.3,’ :CONCENTRATION RATIO (DIM)”/%

.

3 ’ ,1PE1O.3,’ :COLLECTOR AREA (M**2)’/%

, 4 ‘,1PE10.3, ’ :LATITUDE (DEG)’/%

,

5“, IPE1O.3,’ :LONGITUDE (DEG)’/%

,

6 ’ , 1PE10.3, ’ :STANDARD LONGITUDE (DEG)’/%

‘ 14 ‘, IPE10.3, ’ :THERMAL LOSS COEFF (KW/C*M**2)’/%

‘ 17 ‘,lPELO.3,’ :ABSOR6 OF THERMAL-ONLY SURFACES (.LE.l.00)’/%

‘ 28 ‘, 1PE1O.3,’ :COLLECTOR REFLECTIVITY (.LE. 1.00)’)

1124 READ(12,*,PROMPT=’VAR # AND VARIABLE: ‘) IV,V

IF (IV.LE.0) GO T(I 1126

IF (IV.GT.37) GO TO 1124

COLI.3.PB-PNC/UGF002 o8/17/7g 14:48:14

2046.

2047.

20.48.

2049.

2050.

2051.

2052.

2053.

2054.

2055.

2056.

2057.

2058.

2059.

2060.

2061.

2062.

2063.

2064.

2065.

2066.

2067.

2068.

2069.

2070.

2071.

2072.

2073.

2074.

2075.

2076.

2077.

2078.

2079.

2080.

2081.

2082.

2083.

2084.

2085.

2086.

2087.

2088.

2089.

2090.

2091.

2092.

2093.

209.4.

2095.

2096.

2097.

2098.

2099.

2100.

2101.

2102.

2103.

2104.

2105.

2106.

SCEL(IV)=V

GO TO 1124

1126 READ(12,*,PROWT-’FILE NUMBER TO STORE COLLECTOR COEFF: ‘) IV

IF (IV.LE.0) GO TO 1140

REWIND IV

WRITE(IV) SCEL,ISCEL

%

% FINISH INITIAL COMPUTATIONS

%

1140 LAT=LAT/PIEv

TANLAT=TAN(I.AT)

ISYS1=ISYS

DO 50 1-1,365,1

DO 2500 J-1,4

EQ(J)=A(J)*cos ((PIE2* (J-1)*1)/365. 25)+B(J)*sIN( (P1E2*(J-1 )*1)/365.25)

2500 CONTINUE

RISANG-ACOS((-TANLAT)*TAN (DECL(I)))

DAYLEN(I)=PIEV*RIsANG/7.5

soNooN(I)-13.5-((EQ(l)+EQ(2)+EQ( 3)+EQ(4)+4*(LoNGsT-LoNG) )/60)

50 CONTINUE

RETURN

x

% DAILY COMPUTATION BEGINS

%

ENTRY COLLO1(K,TFIN,TFOUT,TA,QSR,ESR)

IF ((RADTH(K).LE.0) .OR. (RADDN(K).I,E.0)) GO T O

TFIN-TFOUT

TAIRwTA-273

I-(K-1)/24

J=K-24*(1)

1-1+1

N-NZDAY(I)

TD=J-O.5-SONOON(I)+DAYLEN (1)/2

IF ((TD.LT.0).oR. (TD.GT.DAYLEN(I))) GO TO 38

TDAY=ABS (SONCX3N(I)-J)

TD-DAYLEN(I)/2.

TB=(TD/(DAYTIM(3,N) ))*DAYTIM(l,N)

TC-(TD/(DAYTIM(3,N) ))*DAYTIM(Z,N )

IF(TDAY.LT.TB)GO TO 25

IF(TDAY.LE.TC)GO TO 26

GO TO 27

25 GAMCOS=O

GO TO 30

26 GAMCOS=(GAMMA(I,N)-GAMMA( 2,N))/(TC-TB)

TD=TB

GO TO 30

27 GAMCOS=(GAMMA(2,N)-GAMMA(3 ,N))/(TD-TC)-

(GAMMA(2,N)-GAMMA(l,N)) /(TDAY-Tc)

TD=TC

30 GAMCOS-GAMMA( l,N)-GAMCOS*(TDAY-TD)

QSR=REFLEC*ALPHA*AREAC*GAMCOS*M.DDN (K)- Z

(TFOUT-TAIR)*ULOSS*AREAC/CWTIO

GO TO 39

38 QSR=O.

39 IF(QSR.LE.0) QSR=O.

RETURN

z

% OUTPUT STATEMENTS

z

ENTRY COLL02

WRITE(13,250)

38

z

@correction FAcToR

I

I

I

i
coLL3. PB-PNc/uc Foo2 08/17/78 14:48: 14

2107. 250 FORMAT (‘ HF:LIOSTAT FIELD’ )

2108. RETURN

2109. z

2110. % oUTPU 1 SLWRY

2111. z

2112. ENTRY COLL03

coLL3. PB-PNc/uGFoo2 08/17/78 14:48:14

2113. LAT=LAT*PIEV

2114. WRITE(13,900) CRATIO,AREAC,LAT,LONG, LONGST,ULOSS, Z

2115. ALPHA,REFLEC

2116. RETURN

2117. END

●
OFFPK.PB-PNCIUGFO02 08117178 14:45:20

1.

2. ‘

3.

4.

5.

6.

7.

8.

9.

10.

11.

12.

13.

14.

15.

1000.

1001.

1002.

1003.

1004.

1005.

1006.

1007.

1008.

1009.

1010.

1011.

2000.

2001.

2002.

2003.

2004.

2005.

2006.

2007.

2008.

2009.

2010.

2011.

Z PROGRAM NAME OFFPK.JB

% JOHN C. BELL

Z ENERGY PROGRAM

% OFFICE OF TECHNOLOGY ASSESSMENT

% COMPILED

z DATE: 3/25/78

z TIME: 15:30:21

% PROGRAM OFFPK.JB FOR BUYING OFFPEAK ELECTRICITY

z

z

z

%

z

.%

SUBROUTINE OFFPK

DIMENSION E(8760),CPC(2,25)

COMMON/DXXK/BOLMAX,CPC

COMMON/EXXX/TAXRF

COFillON/XDATA/E

DATA X1l.A.X,ONE/l.OEIO, l./

READ(12, 99,PROMPT-’HEATING, COOLING, AND HoT wATER: ‘) ~TsT

99 FoRMAT(A4)

IF (ITST.EQ.’YES’) IHC=l

READ(12,*,PROMFT-”OFFPEAK CHARGING HOURS--BEGIN AND END: ‘) IHRB,IHRE

IHRTOT-IHRE-IHRB+l

RETURN

ENTRY OFFPK1(K,QP,QC,QSH,COPEE, EHWEFF)

IHR-K-((K-l )/24)*24

IF ((IHR.GE.IHRB) .AND. (IHR.LE.IHRE)) GO TO 200

H20N-H20NtQP

CALL UPDATE(XMAX,WSTOR,-QP,RESID,ONE,ONE,XMAX)

E(K)=E(K)-(QP-RESID)/EHWEFF

IF (QsH.GT.o) GO TO 100

HEATN=HEATN+QC

CALL UPDATE(XMAX,HSTOR,-QC,RESLD,ONE,ONE,XMAX)

CO TO 101

100 IF (IHC.NE.1) RETURN

COOLN-COOLN+QC

OFFPK. PB-PNC/UGFO02 08/17/78 14:45:20

2012.

2013.

2014.

2015.

2016.

2017.

2018.

2019.

2020.

2021.

2022.

2023.

2024.

2025.

2026.

2027.

2028.

2029.

2030.

2031.

2032.

2033.

2034.

2035.

2036.

2037.

2038.

2039.

3000.

3001.

3002.

3003.

3004.

3005.

3006.

3007.

3008.

3009.

3010.

CALL UPDATE(XMAX,CSTOR,-QC,RESID,ONE,ONE,XMAX)

101 RESID=(QC-RESID)/COPEE

E(K)-E(K)-RESID

QC2-QC2+RESID

QC1=QC1-RESID

RETURN

200 IF (IHR.NE.IHRB) CO TO 250

OFFBYH=AMAXI(O, (HEATN-HSTOR) /IHRTOT)

OFFBYC=AMAX1(O, (COOLN-CSTOR)/IHRTOT)

OFFBYW=AMAKI(O, (H20N-WSTOR) /IHRTOT)

HEATN=O

COOLN=O

H20N=0

250 E(K)=E(K)@FFBYW/EHWEFF+OFFBYH

IF (IHC.NE.1) GO TO 275

CALL COPT(TAIRF,CPC,COPC)

E(K)=E(K)H3FFBYC/COPC

CSTOR=CSTOR+OFFBYC

TOFFPC=TOFFPCiOFFBYC/COPC

275 HSTOR=HSTOR+OFFBYH

TOFFPH=TOFFPH+OFFBYH

WSTOR-WSTOR+3FFBYW

TOFFPW-TOFFPWWFFBYW/EHWEFF

IF (IHR.NE.I~E) RETURN

HSTORM=AMAX1 (HSTOR,HSTORM)

CSTORM=AMAXI (CSTORM,CSTOR)

WSTORM=AMAX1 (WSTORM,WSTOR)

RETURN

ENTRY OFFPK2

IF (IHc.EQ.1) wR1TE(13,7)

7 FORMAT(//’ OFFPEAK BUYING FOR HEATING,COOLING, AND HOT WATER’)

IF (IHc.NE.1) WRITE(13,8)

8 FORllAT(//’ OFFPEAK BUYING FOR HEATING AND HOT WATER’)

WRITE(13,9) HSTORM,TOFFPH,CSTORM,TOFFPC,WSTORM,TOFFPW

9 FORMAT( 15X, ’MAXIMUM’ ,5x, ’ToTAL’ /l5x,’sToRAGE’ ,2x,’Electricity”/%

‘ HEATING:’ ,fLX,2( lPE10.3,2X)/’ COOLING: ’,4X,2(1PE1O. 3,2x)/%

‘ HOT WATER: ‘,2(1PE1O.3,2X))

RETURN

END
Chapter IV

RESULTS OF SYSTEMS ANALYSIS
Chapter lV.—RESULTS OF SYSTEMS ANALYSIS

Page

A Guide to the Tables . . . . . . . . . . . . . . . . . . . . . .96

The Summary Tables . . . . . . . . . . . . . . . . . . . . . . 99

The Catlog of Energy Systems. . .. .. . .. .. 147

Single Family Homes

Albluquerqe. . . . . .. . . . . .. ......................148

.... . . . . . . . . . . . . . . ... .....201

Fort Worth ● ..... . . . . . . . . . . . . . . . . . . . 239

Omaha . ● . . . . . . . . . . . . . . . . . . . . . . 268

High Rise Apartments

Albuquerque .. ......................350

Boston ● ....*. . . . . . . . . . . . . . . . . . . . . . . 396

Fort Worth . . . . . . .. . . . . . . . . . . . . . . ...* 410

Omaha . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .423

page Shopping Centers

Albuquerque ● .... . . . . . . . . ● ... . 510

Fort Worth . . . . . . . . ● . ● . . . ● ● . . . . 531

Omaha.. . . . . . . . . . . . . . . . . . . . . . . 645

Communities

Albuquerque .. .. .. .. .. .. .. ...; ......677

Fort Worth . . . . . . . . ..... . . . . . . . . . . . 694

Omaha. ● . . ● ● . . . . . . ● . ● . . ● ● ● . . . ● .,. . . . . 601

Industrial Buildings

Albuquerque . . . . . . . .,..,......, ● 616

Omaha . . . . . . . . . . . . .9 .......9........637
Chapter IV

Results of Systems Analysis

The tables, which constitute the bulk of this chapter, provide detailed information about a number of integrated solar energy systems designed to meet

the energy needs of single family houses, apartment buildings, shopping

malls, communities, and industrial plants located in Albuquerque, N. Mex.;

Boston, Mass.; Fort Worth, Tex.; and Omaha, Nebr. This extensive catalog

was prepared to compare, on an equitable basis, the performance of the enormous variety of systems that are capable of meeting the energy requirements

of these buildings and communities. The examples have been chosen to indicate the relative attractiveness of a number of different system components, which may become available during the next decade, and to indicate

the facility with which different combinations of components work together

as integrated systems.

This chapter is divided into two major parts:

1.

2.

Chapter

A summary table giving the monthly costs for each system analyzed and

the effective cost of solar energy generated by each system (this table

also serves as an index to the catalog tables, which provide details about

each system); and

A catalog of solar energy systems which devotes one page to eac h

system, summarizing the assumptions made in analyzing its per -

formance.

I of this report discusses the

methods used to evaluate the economic

parameters illustrated in the tables. It provides a simple technique for performing an

accurate Iife-cycle cost analysis of energy

systems that may be owned by any of several different types of owners. it also

discusses the origin of the assumptions

made about the financing and tax status of

each type of owner. The methodology and

data described in this chapter are used in a

computer program that calculates the levelized monthly costs for each system; supplies

information about the first costs, operating

costs, and lifetimes of the system components; the fossil and electrical energy purchased; the assumed escalation rate of

energy prices; and the type of owner.

Chapter I I discusses the assumptions

made about current and future prices of oil,

gas, coal, and electricity. It provides information about the price charged for

energy now on the market, the marginal cost

of new energy sources, the cost of energy

from sources likely to be available by the

year 2000, and the time over which a transition from one source to another is likely to

occur. A simple mathematical method is

presented that can translate differing

estimates about future energy sources an d

costs into a forecast of prices that can be

used in Iife-cycle cost analysis,

Chapter III discusses the computer programs that compute the amount of fuel and

electricity that must be purchased annually

to meet the energy needs of the building or

community. These programs compute the

amount of energy that can be provided by

any solar energy system used; the purchased

energy is the difference between onsite

demands and available onsite solar energy.

Chapter V discusses the assumptions

made about the cost and performance of

each subsystem used in the analysis and provides detailed information about the buildings being analyzed and assumptions made

about the energy consumed by the buildings.

An attempt was made to reduce the

results of the somewhat complex analysis

presented in this report to a set of simple,

easily interpretable numbers—a monthly

energy bill and an effective solar energy

cost in ¢/kWh.

95
96 ● Solar Technology to Today’s Energy Needs

A GUIDE TO THE TABLES

Two types of numbers are provided to

represent the costs of the systems examined:

1 ) a set of Ievelized monthly costs perceived

by the energy consumer, with various

assumptions about tax credits given and the

price of nonsolar energy, and 2) a cost in

¢/kWh of solar energy (or energy conservation) obtained by comparing it with a “reference system. ” The reference system represents a conventional energy system operating in a building identical to the one used

to analyze the performance of the solar or

energy conservation system. An attempt is

made to choose a reference system that

most nearly resembles the system used to

provide backup energy for the solar energy

device.

THE SUMMARY TABLES

The summary tables provide the following

information about each system examined:

●

●

●

A brief descriptive title and an identifying number.

The percentage of the energy used by

the reference system that is supplied by

the solar energy system. If an energy

conservation device is employed that

does not use solar energy, this number

represents the percentage energy saving. The formula for this percentage (Ps

)

is as follows:

subscript “r” refers to the reference system, subscript “t” refers to the test system, i.e., the system being compared

with the reference system.

The effective cost of solar energy with

and without an investment tax credit.

(When a conservation system is shown

which does not use solar energy, this

cost refIects the effective cost of saving

●

●

energy using the conservation device. )

In some cases, the life-cycle cost of the

energy conservation system (excluding

the cost of energy purchased) is actually lower than the life-cycle cost of the

reference system (excluding the cost of

energy purchased) resulting in a situation where the effective cost of the

energy conserved is negative.

C = Ievelized annual capital costs

(including financing charges,

taxes, and insurance)

OM = Ievelized annual operating and

maintenance costs (excluding

purchases of electricity and

fuels)

CR = Ievelized cost of replacements

The Ievelized monthly energy costs for

the set of owner types described below

make four different assumptions about

the kinds of tax credits given and the

cost of conventional energy.

A table number that indicates the number of the table in the catalog which

describes the system in more detail.

When a single number appears in this

column, the catalog page corresponds

exactly to the summary case. When two

numbers appear, the first table number

shown describes an identical system,

but some of the costs (usually collector

costs) shown in the table are not the

same as those used to compute the

costs shown in the summary table. The

second catalog page referenced describes a slightly different system (e. g.,

it might have a different CoIIector area),

but the unit costs of the components

are the same as those used to compute
Ch. IV Results of Systems Analysis ● 97

the costs shown on the line in the summary table, (This method was used to

minimize the number of catalog pages. )

When the letter “G” appears with a

table number, the catalog page referenced describes an identical system

which assumes oil fuel prices while the

costs shown in the summary table

assure that gas was the fuel used. When

the letter “M” appears with a table

number in the summary table the catalog page referenced describes an identical system owned by an industrial corporation, while the summary table

shows the economics for municipal utility ownership. When the letter “T” appears with a table number, the catalog

page referenced describes an identical

system with ordinary electric rates

while the costs shown in the summary

table assume that marginal or “time-ofday” rates are charged.

The tables indicate the costs resulting from

financing by a homeowner (for single family

houses), by a real estate partnership (for

apartments and shopping malls), by a municipal utility (for community systems and

industries), and by an industrial corporation

requiring a 20-percent return on investments

(for industries).

Each of these costs is paired with a cost

that would result if the additional solar or

conservation equipment were owned instead by a privately owned utility. Here, it is

assumed that the owner other than the private utility owns a share equal in value to

the cost of the reference energy system (i. e.,

the backup system, in most cases).

THE CATALOG OF ENERGY SYSTEMS

Each page of the catalog is devoted to a

single energy system designed to serve the

building and the city indicated. The pages

are divided into three parts:

●

●

A drawing of the building giving a

rough indication of the external appearance of the system.

An energy flow-diagram indicating the

way i n which CoIIectors, storage devices, engines, and energy-consuming

devices are combined to meet the energy demands of the buildings.

A set of three tables providing details

about the costs and performanc e

assumed for the system.

– Table A provides an itemized cost list

of all components used in the system.

it includes an estimate of the first

cost, the annual operating and maintenance costs (exclusive of purchased energy) which are charged during

the first year of the systems operation, and the expected lifetime of

the component (rounded to 10, 15, or

30 years).

The second part of the table i n -

dicates the amount of nonsolar energy (electricity or fossil fuel) that was

purchased to provide backup for the

solar energy system. In the case of

electricity the amount shown is the

difference between the amount purchased from an electric utility and

the amount sent from the onsite generating equipment back into the electric grid for possible purchase by the

utility. The peak amount of electricity purchased during any hour of the

year is also shown.

– Table B provides estimates of the

Ievelized monthly costs for a system

that begins operation in 1976, and

also for a similar system that would

begin operations in 1985. The only

difference between the 1976 cases

and the 1985 cases is that the conventional energy prices in the 1985 cases

have escalated to a higher level by

the startup date, as shown in chapter

II. For ease of comparison with the

1976 cases, prices have not been inflated between 1976 and 1985 for the

1985 cases (i.e., all cases start in 1976

dollars, and cost inflate at 5.5 percent in each succeeding year). With

the advanced solar energy systems,

the 1976 costs are shown only for reference purposes; they are not meant

to suggest that al I technologies examined were available in 1976. The lev-
98 ● Solar Technology to Today’s Energy Need s

elized cost of the reference system is

also shown for comparison.

The costs achieved with a 20-percent

investment tax credit (ITC) could also

be reached with low interest loans

and other incentives. The table below

shows the interest rate of a loan

which would result in the same annual capital costs (k1

) as a 20-percent

ITC.

The costs achieved with “full incentives” assumed a combination of 20-

percent investment tax credit, 3-year

straight-line depreciation, and exemption from property taxes. These

cost reductions could also b e

reached with tax credits or other incentives.

Loan interest

k, (baseline fraction Loan interest

Owner 20% ITC financed) (95% financed)

Homeowner, new construction 0075 0.033 0.065

Homeowner, retrofi t 0.092 0.048 0.043

Real estate owne r 0.067 0.019 0.070

Industry (20% IRR) .................... 0.23 9 — 0.27 4

Municipal utility . 008 1 0.041 0.041

Private utilit y 0.12 6 0.066 0.045

k1 Full Equivalent

Owner incentives ITC (%)

Homeowner, new

constructio n 0.031 65

Homeowner, retrofi t 0,048 65

Real estate owner 0.022 43

Industry (20% IRR) ..... 0.111 58

Municipal utility . . . . 0.061 50

Private utility, . . . . 0.071 53

– Table C provides an estimate of the

effective cost of solar (or conservation) energy computed using the

technique described in the description of the summary tables. The cost

of conventional electricity and fuels

Ievelized over the same time interval

are provided for comparison.

I
Summary description of system Table

numbe r

ALBUQUERQUE SINGLE FAMILY

Reference system

Conv. Gas Heat, Gas Hot Water, and Central

Electric A/C (SF-1) . . . . . . . . . . . . . . . . . . . . . . 1

SUMMARY TABLE LISTING

Effective cost of solar Levelized monthly cost

Percent energy (¢/kWh) of energy service

,

solar N o 2 0 % Project Ion 1 Project Ion 2 Projection 2 Projection 3

credits ITC No credits No credits 20°A ITC 20% ITC

0.0 NA/

Systems compared to reference system

Conv. Improved Gas Heat, Hot Water, and

Central Electric A/C. . . . . . . . . . . . . . . . . . . . . 2 11.9 71/

Conv. Insulated House; Gas Heat and Hot

Water and Central Electric A/C . . . . . . . . . . . 3 168 .26/

Solar Hot Water; Flat-Plates (1977 Prices);

SF-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 15.9 6.1 9/

Solar Hot Water; Flat-Plates (Future Price);

SF-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5 15.9 4.45/

Solar Heating; Flat-Plates (1977 Prices), LowNA NA/ NA 116. / NA 173. / NA 173. / NA

5.81 .62/ 5.7 3 111,1 123. 160, / 172. 159. / 172.

3.98 .02/ 3.7 7 106. / 119. 153. / 166. 152, / 165.

2.61 5.22/ 11.78 127. / 148. 1 73./ 195. 170. / 192.

0.04 3.75/ 9.44 121. / 140, 167./ 186. 165. / 184.

Temp. Storage; SF-1 ... . . . . . . . . . . . . 6 41.0 9.47/ 15.25 8.02/ 14.01 172./ 222, 201. / 251. 188. / 240.

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; SF-1 . . . . . . . . . . . . . . . . . . . . 7 41.0 6.12/ 10.34 5.18/ 9.5 3 143./ 179. 172. / 208. 164. / 201.

287./ N A

265./ 278.

253./ 266.

273./ 295.

268. / 287.

276.1 328.

251. / 289.

Reference system

Conv. Oil Heating and Central Electric A/C

(SF-5) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Systems compared to reference system

Conv. Improved Oil Heating and Central Electric A/C (SF-5). . . . . . . . . . . . . . . . . . . . . . . . . .

Conv. Insulated House; Oil Heating and Central Electric A/C (IF-5) . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-Plates (1977 Prices);

SF-5 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-plates (Future Price);

SF-5 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices); LowTemp. Storage; SF-5 . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; SF-5 . . . . . . . . . . . . . . . . . . . .

8 0.0 NA/ NA NA/ NA 179. / NA 230./

9 11.5 .63/ 5.9 4 .55/ 5.8 7 163. / 178. 208./

10 18.5 -.10/ 3.1 6 -.25/ 3.0 3 153./ 167. 1 95. /

11 18.0 4.76/ 10.17 4.01/ 9.5 3 173./ 197. 216./

1 1/135 18.0 3.42/ 8.1 9 2.88/ 7.7 3 168. / 188. 210./

12 45,4 7.46/ 12.20 6.32/ 11.22 194./ 246. 222./

1 2/137 45.4 4.82/ 8.3 3 4.08/ 7.69 165./ 204. 193./

NA

223.

209.

239.

230.

274.

231.

230./ N A

208./ 223.

194. / 209.

212./ 236.

207./ 228.

209./ 263.

185./ 224.

—

458. / NA

406. / 421.

379. / 393.

396./ 420.

392. / 413.

326. / 380.

302. / 341,
—.

Effective cost of solar Levelized monthly cost

Summary description of system Table Percent energy (¢/kWh) of energy service

numbe r solar No 2 0 % Project Ion 1 Project ion 2 Project Ion 2 Projection 3

credits ITC No credits No credits 20%ITC 20% ITC

Reference system

Conv. Gas Heat, Hot Water, and Absorption

A/C (IF-7) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 0.0

Systems compared to reference system

NA/ NA NA/ NA 122./ NA 187. / NA 187. / NA 295./ N A

Solar Heating and Cooling; Flat-Plates (1977

Prices); Low-Temp. Storage; SF-7 ... , . . . . . 14 56.2 6.55/ 10.87 5.55/ 10.01 165./ 219. 190. / 244. 178./ 233. 248./ 304.

Solar Heating and Cooling; Fiat-Plates (Future

Price), Low-Temp. Storage; SF-7 . . . . . . . . . . 15 56.2 4.24/ 7.48 3.59/ 6.9 3 137. / 177. 161./ 202. 153, / 195. 224. / 265.

16

Reference system

Conv. Insulated House; Gas Heat, Hot Water,

and Absorption A/C (1 F-7) . . . . . . . . . . . . . . . . 0.0

Systems compared to reference system

Solar Engine Cogeneration, Insulated House;

ORCS With Cooling Tower, One-Axis

Tracker (Future Design), Low-Temp.

Storage; IF-7. . . . . . . . . . . . . . . . . . . . . . . . . . . . 17 42.2

Solar Engine Cogeneration, Insulated House;

ORCS With Cooling Tower, One-Axis

Tracker (Future Design), High-Temp.

Storage, Gas Backup; IF-7 . . . . . . . . . . . . . . . 18 67.8

Solar Engine Cogeneration, Insulated House;

ORCS With Cooling Tower, One-Axis

Tracker (Future Design), Battery and HighTemp. Storage, Gas Backup; IF-7 . . . . . . . . . 19 63.7

Conv. Engine Cogeneration, insulated House;

Stirling Engine (Low Eff.) Direct-Drive Heat

Pump, Gas Hot Water; IF-9. . . . . . . . . . . . . . . 20 45.6

Reference system

Conv. System, All Electric; Heat Pump (SF-1).

Systems compared to reference system

Conv. System, All Electric; Improved Heat

Pump (High Price) (SF-2). . . . . . . . . . . . . . . . .

Conv. System, All Electric; Improved Heat

Pump (Low Price) (SF-2) . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-Plates (1977 Prices);

SF-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-Plates (Future Price);

SF-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

21 0.0

22 14.5

23 14.5

24 28.4

24/1 50 28.4

NA/ NA

14.66/ 22.99

10.26/ 15.99

12.75/ 19.52

5.45/ 8.2 8

NA/ NA 110. / NA 163. / NA 163. / NA 260./ N A

12.71 / 21.32 184. / 249. 218./ 283 . 203./ 270. 235./ 302.

8.84/ 14.77 183./ 255. 203./ 275 . 185. / 259. 203. / 277.

11.02/ 18.05 207./ 287. 229./ 309 . 209. / 291. 229. / 312.

5.23/ 8.0 9 113. / 137. 146. / 170. 144./ 168. 174. / 198.

NA/ NA NA/ NA 156. / NA 203. / NA 203./ NA 395./ NA

5.27/ 10.32 4.78/ 9.9 1 162. / 181. 203./ 222 . 201./ 221. 367./ 387.

1.34/ 4.97 1.22/ 4.8 7

2.67/ 5,5 1 2.25/ 5.1 5

1.91 / 4.39 1.61/ 4.1 3

46. / 160. 187. / 201. 187. / 201. 353./ 367.

47,/ 169 . 182. / 204. 179. / 201. 321./ 343.

41./ 160 . 176. / 195. 174. / 193. 316./ 336.
Systems compared to reference system—Continued

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; SF-2 ... . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices); SF-2

Solar Heating; Flat-Plates (Future Price); SF-2

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; SF-2 ... . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; SF-2 . . . . . . . . . . . . . . .

100-Percent Solar Heating; Flat-Plates (1977

Prices), Community Seasonal Low-Temp.

Storage; SF-2 . . . . . . . . . . . . . . . . . . . . . . . . . .

100-Percent Solar Heating; Flat-Plates (Future

Price), Community Seasonal Storage; SF-2

PV System; Air-Cooled Si Arrays ($0.50/W);

SF-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Thin-Film Arrays

($0.10/W); SF-2 . . . . . . . . . . . . . . . . . . . . . . . .

PV Cogeneration: One-Axis Concentrator With

Si Cells ($15/W Cells), Multitank Low-Temp.

Storage; SF-2 . . . . . . . . . . . . . . . . . . . . . . . . .

Reference system

Conv. Insulated All Electrlc House; Heat

Pump (IF-2) . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Systems compared to reference system

PV System, Insulated House; Air-Cooled Si

Arrays ($1/W); IF-2 . . . . . . . . . . . . . . . . . . . . . .

PV System, Insulated House; Air-Cooled Si

Arrays ($0.50/W); IF-2. . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Si Arrays ($0.50/W),

Battery Storage; IF-2 . . . . . . . . . . . . . . . . . . . .

PV System, Insulated House; Air-Cooled Si

Arrays ($0.50/w); Improved IF-2 . . . . . . . . . . .

PV System, Insulated House; Air-Cooled ThinFilm Arrays ($0.30/W); IF-2 . . . . . . . . . . .

PV System, Insulated House; Air-Cooled ThinFilm Arrays ($0.10W); IF-2 . . . . . . . . . . . . . . .

PV System, Insulated House; Air-Cooled ThinFilm Arrays ($0.10IW); Improved SF-2.

PV Cogeneration, Insulated House; One-Axis

Concentrator With Si Cells ($15i/W) Cells),

Multitank Low-Temp. Storage; IF-2 .

PV Cogeneration, Insulated House; Plastic

Dye PV Concentrator, Multitank Low-Temp.

Storage; IF-2. . . . . . . . . . . . . . . . . . . . . . . . . . .

PV System, Insulated House; Plastic Dye PV

Concentrator With Passive Cooling; IF-2. . .

25

26

26/1 54

27

27/154

28

29

30

31

32

33

34/1 71

34

35

36

37

38

39

40

41

42

37.0

41.4

414

48.4

484

65.4

65.4

85.6

59.9

92.7

0.0

51.9

51.9

45.2

61.2

29.1

37.5

46,2

76.7

100.8

90.0

5.22/ 88 3

5 32/ 88 6

3 53/ 624

6.22/ 10.04

4 .02/ 682

7.17/ 11 20

4.36/ 7.00

5.291 8.31

2 .05/ 3.78

11 .66/ 17.65

NA/ NA

9.68/ 15.33

5.37/ 9.0 0

8.50/ 13.49

4.78/ 7.9 4

4.24/ 8.2 3

2.05/ 4.5 8

 1.99/ 415

8.95/ 13.89

2.63/ 4.4 1

2.36/ 4.1 2

4 43/ 81 6

451 / 81 7

2.98/ 57 8

5 26/ 9.2 3

3.40/ 6.2 9

5.90/ 10.12

3.62/ 6.37

4.44/ 7,59

1.72/ 3.50

9.81 / 16.08

NA/ NA

8.15/ 14.03

4.53/ 8.2 8

7.32/ 12.49

4.04/ 7.3 1

3.55/ 7.6 4

1.71 / 4.29

1.69/ 3.89

7.55/ 12.69

2.21 / 4.05

1.98/ 3.8 0

170 / 206.

172 I 212.

152. I 183

187 / 237.

158 / 195.

214. / 286.

165. / 211.

213./ 284 .

141 ./ 169.

358. / 508.

142. / NA

222./ 291 .

170. / 214.

190. / 243.

165. / 210.

148./ 175.

132./ 154.

127. / 151.

235./ 323 .

124. / 166.

1 33. / 170.

201 I 237

202. / 241.

182 / 212

213 / 263

184 / 221

234. / 305

184. / 231

234. / 304.

169. / 197.

368. / 519.

183. / NA

249./ 317 .

197. / 241.

215./ 267 .

188./ 233.

180./ 207.

162./ 184.

154./ 177.

249. / 337.

1 33. / 175

150. / 187.

193. / 230.

193. I 234.

176. / 207

201. / 253.

176 / 214

211 / 286.

171 / 219

215 I 288.

163. / 192.

322. / 479.

321 ./ 358

313. / 354.

295 I 327

309. / 361

284. / 322.

290 I 364

249./ 29 8

299. / 372

276./ 305.

364 / 521.

183. / NA

230./ 302.

187./ 232.

202. / 257.

178. / 224.

175. / 203.

159. / 181.

151. / 175.

224./ 316.

123. / 166

142. / 181.

350./ N A

338./ 409.

294./ 340.

303./ 357.

272. / 319,

306./ 333.

281./ 303.

260./ 283.

282. / 374.

160. / 203

214. / 252.
Effective cost of solar Levelized monthly cost

Summary description of system Table Percent energy (¢/kWh) of energy service

numbe r sola r N o 200/0 Project Ion 1 Projection 2 Projection 2 Projection 3

credits ITC No credits No credits 20% ITC 20% ITC

Systems compared to reference system—Continued

PV System, Insulated House; Air-Cooled Si

Arrays ($0.50/W), Low-Temp. Storage; Improved IF-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . 43

—

Reference system

Conv. All Electric House; Resistance Heat

and Window A/C (SF-3). . . . . . . . . . . . . . . . . .

Systems compared to reference system

Conv. All Electric House; Resistance Heat

and Window A/C, 65/85 Thermostat (SF-3). .

Conv. Insulated All Electric House;

Resistance Heat and Window A/C (IF-3). . . .

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; SF-4 . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; SF-4 . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; SF-4 . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; SF-4 . . . . . . . . . . . . . . . . . . . .

ALBUQUERQUE SINGLE FAMILY

TIME-OF-DAY RATES

Reference system

Conv. All Electric House (SF-3); Marginal Electric Rates. . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Systems compared to reference system

Conv. Off-Peak Electric Heating; Window A/C,

Low-Temp. Storage (SF-4). . . . . . . . . . . . . . . .

Conv. Off-Peak Electric Heating and Cooling

System; Central Electric Chilling, LowTemp. Thermal and Cold Storage (SF-4). . . .

Solar Off-Peak Heating; Flat-Plates (1977

Prices), Low-Temp. Storage; SF-4 . . . . . . . . .

Solar Off-Peak Heating; Flat-Plates (Future

Price), Low-Temp. Storage; SF-4 . . . . . . . . . .

Solar Off-Peak Heating and Cooling; FlatPlates (1977 Prices), Low-Temp. Storage;

SF-4 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Off-Peak Heating and Cooling; FlatPlates (Future Price), Low-Temp. Storage;

SF-4 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

44

45

48

49 ‘

491192

52

53

73.9

0.0

4.2

21.5

47.0

47.0

56.2

67.2

5.75/ 8.8 7

NA/ NA

-.00/ 5.2 7

.37/ 1.6 3

3.47/ 5.5 4

2.31/ 3.8 3

3.98/ 6.2 3

2.83/ 4.4 8

5.02/ 8.2 4 157. / 211. 177. / 231. 164./ 220. 182./ 238.

NA/ NA

-.00/ 5.2 7

.251 1.5 3

2.94/ 5.0 9

1.95/ 3.5 3

3.37/ 5.7 0

2.39/ 4.1 1

177./ NA

171 ./ 179.

149./ 159.

169./ 205.

149./ 176.

179./ 224.

151./ 191.

238. / NA

230./ 238 .

198./ 208.

204./ 240 .

184./ 211.

208./ 254 .

174. / 215.

238./ NA 490./ NA

230./ 238. 472./ 480.

197./ 207. 399./ 409.

195. / 232. 337./ 374.

178. / 205. 320. / 347.

196./ 243. 317. / 364.

163./ 205. 259./ 301.

T44 0.0 NA/ NA NA/ NA 241./ - NA 241./ NA 241./ NA 241./ NA

46

-.6 -96.34/ ● ***** -75.80/ ● ***** 183./ 204. 183./ 204. 1 79./ 200. 179./ 200.

47

1 ● *****, ● ***** ● *****/ ● ***** 197./ 232. 197./ 232. -. 188./ 225. 188./ 225.

50

46.7 4,06/ 6.4 2 3.42/ 5.8 7 196./ 236. 196,/ 236. 185./ 227, 185./ 227.

50/194

46.7 2.88/ 4.7 0 2.42/ 4.3 1 176./ 207. 176./ 207. 168./ 200. 168./ 200.

51 47.2 6.28/ 9.6 9 5.33/ 8.8 9 212./ 271. 212./ 271 . 196./ 258. 196./ 258.

51/196 47.2 5,12/ 8.0 0 4.35/ 7.3 4 192./ 242. 192./ 242. 179./ 231. 179./ 231.
BOSTON

Reference system

SINGLE FAMILY

Conv. Gas Heat, Hot Water, and Central Electric A/C (SF-1). . . . . . . . . . . . . . . . . . . . . ... , .

Systems compared to reference system

Conv. Improved Gas Heat, Hot Water, and

Central Electric A/C (SF-1) . . . . . . . . . . . . . . .

Conv. Gas Heat, Hot Water, Central Electric

Chilling, 65/85 Thermostat (SF-l). . . . . . . .

Solar Hot Water; Flat-Plates (1977 Prices);

SF-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Hot Water; Gas Heat, Central Electric

AIC; SF-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; SF-1 . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; SF-1 . . . . . . . . . . . . . . . . . . . .

54 0.0

55 12.8

56 5.5

57 12.0

57/125 12.0

58 34.1

58/127 34.1

NAI NA

.73/ 5.92

-.00/ 11.36

9.46/ 19.01

6.66/ 14.88

15.44/ 24.47

9.80/ 16,19

NAI NA

.64/ 5.8 4

-.00/ 11.36

7.97/ 17.74

5.61/ 13.98

13.06/ 22.44

8.28/ 14.89

204. / NA

188. / 202.

193. / 206.

211./ 235.

204./ 225 .

266. / 330.

226./ 272 .

328. / NA

293./ 307 .

312./ 325 .

317.1 341.

310./ 331 .

340./ 404 .

300./ 345 .

328. / NA 549./ NA

293. / 307. 496. / 510.

312./ 325. 514./ 527.

314./ 338. 518./ 542.

308./ 329. 512./ 533.

323./ 390. 498. / 564.

289./ 336. 464./ 511.

Reference system

Conv. Insulated House; Gas Heat, Hot Water,

and Central Electric A/C (IF-1) . . . . . . . . . . . . 59 0.0 NA/ NA NAI NA 174./ NA 266./ NA 266. / NA 456./ NA

Systems compared to reference system

Conv. Insulated House; Improved Gas Heat,

Hot Water, and Central Electric A/C (IF-1) . 60 12.3 .74/ 7.9 7 .65/ 7.8 9

Conv. Insulated House; Oil Heat and Central

Electric A/C (IF-5). . . . . . . . . . . . . . . . . . . . . . . 61 -12.9 -3.74/ -11.07 -3.53/ -10.89

Conv. Insulated House; Gas Heat, Hot Water,

and Absorption Cooling (IF-7) . . . . . . . . . . . . 62 -3.5 -5.61 I -35.64 -3.86/ -34.15

Conv. Engine Cogeneration; Insulated House;

Stirllig Engine (Low Eff.), Heat Pump, Gas

62./ 176 . 240./ 255 . 240./ 255. 416. / 431.

96./ 211 . 303./ 318 . 303. / 318. 506./ 521.

76./ 193 . 277./ 294 . 276. / 293. 455./ 472.

Hot Water, Low-Temp. Storage, Gas

Backup; IF-9 . . . . . . . . . . . . . . . . . . . . . . . . . . . 63 42.8 5.23/ 8.4 4 4.92/ 8.1 7 134./ 157. 200./ 222 . 198. / 221. 259./ 282.

Reference system

Conv. Oil Heat and Central Electric A/C (SF-5) 64 0.0 NA/ NA NA/ NA 230./ NA 301./ NA 301./ NA 609./ NA

Systems compared to reference system

Conv. Improved Oil Heat, Gas Hot Water, and

Central Electric A/C (SF-5) . . . . . . . . . . . . . . . 65 13.9 .57/ 5.4 4 .50/ 5.3 8 211.1 227. 274./ 290 . 274./ 290. 546.1 563.

Conv. Oil Heat and Central Electric A/C, 65/85

Thermostat (SF-5). . . . . . . . . . . . . . . . . . . . . . . 66 4.7 -.00/ 13.48 -.00/ 13.48 219./ 235 . 285./ 301 . 285./ 301. 575./ 590.

Solar Hot Water; Flat-Plates (1977 Prices);

SF-5 ., . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 67 13.0 7.56/ 15.98 6.37/ 14.96 234./ 260 . 298./ 324 . 294./ 321. 568./ 595.

Solar Hot Water; Flat-Plates (Future Price);

SF-5 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 67/135 13.0 5.32/ 12.67 4.48/ 11.96 227.1 250. 291./ 314 . 288./ 311. 563./ 586.

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; SF-5 . . . . . . . . . . . . . . . . . . . . 68 36.9 12.35/ 19.85 10.45/ 18.23 283./ 350 . 334./ 400 . 317. / 386. 530./ 599.

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; SF-5 . . . . . . . . . . . . . . . . . . . . 68/1 37 36.9 7.84/ 13.22 6.62/ 12.19 243./ 291 . 294.1 341. 283. / 332. 496. / 545.
Effective cost of solar Levelized monthly cost

Summary description of system Table Percent ,

energy (¢/kWh) of energy service

numbe r sola r N o 200/0 Projection 1 Projection 2 Projection 2 Projection 3

credits ITC No credits No credits 20% ITC 20%IT C

Reference system

Conv. Gas Heat, Hot Water, and Absorption

A/C (SF-7) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 69 0.0 NA/ NA NA/ NA 208./ NA 341./ NA 341./ NA 552./ NA

Systems compared to reference system

Solar Heating and Cooling; Flat-Plates (1977

Prices); Low-Temp. Storage; SF-7 . . . . . . . . . 70 42.2 12.12/ 19.69 10.25/ 18.09 258./ 326. 326./ 395. 310./ 380. 461./ 532.

Solar Heating and Cooling; Flat-Plates (Future

Price); Low-Temp. Storage; SF-7 . . . . . . . . . . 70/143 42.2 7.69/ 13.19 6.50/ 12.17 218./ 267 . 287./ 336. 276./ 327. 427./ 479.

Reference system

Conv. All Electric House; Heat Pump (SF-2) . .

Systems compared to reference system

Conv. All Electric House; Improved Heat

Pump (SF-2) . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-Plates (1977 Prices);

SF-2 . . . . . . . . . . . . . . . . . . . . ... , . . . . . . . . . .

Solar Hot Water; Flat-Plates (Future Price);

SF-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; SF-2 . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; SF-2 . . . . . . . ., . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; SF-2 . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; SF-2 . . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Si Arrays ($50/W); SF-2

PV System; Air-Cooled Thin-Film Arrays

($10/W); SF-2. . . . . . . . . . . . . . . . . . . . . . . . . . .

PV Cogeneration; One-Axis Concentrator With

Si Cells ($15/W Cells); Multitank Low-Temp.

Storage; SF-2 . . . . . . . . . . . . . . . . . . . . . . . . . .

NA/ NA NA/ NA 261./ NA

239./ 254.

248./ 272 .

241./ 261 .

254./ 290 .

233./ 261 .

298./ 362 .

258./ 303 .

305./ 376.

242./ 274 .

448. / 599.

349./ NA

317./ 332 .

321./ 345 .

314./ 335.

321./ 358 .

301./ 329 .

357./ 421 .

317./ 362 .

362./ 433 .

307./ 339 .

494./ 645 .

71 0.0 349./ N A 709./ N A

72

73

73/1 50

74

74/154

75

75/154

76

77

15.2 1 .31/ 4.85

8.25

6.46

10.04

6.40

15.30

10.12

12.05

6.33

1 .19/ 4.74

7.71

6.07

9.08

5.76

14.03

9.31

11.01

5.83

316./ 331.

318./ 342.

312./ 333.

312.1350.

295. / 323.

340./ 407.

306./ 353.

343./ 416.

301./ 333.

631./ 646.

617./ 642.

611. / 632.

587./ 626.

570./ 599.

581.1 647.

547./ 594.

574./ 648,

565./ 598.

20.4

20.4

4.08/

2.86/

3.44/

2.41/

28.7 5.48/ 4.36/

28.7 2.99/ 2.24/

40.3

40.3

57.0

9.64/

6.12/

7.64/

3.53/

8.15/

5.17/

6.42/

40.2 2.95/

78 63.3 16.44/ 24.93 13.84/ 22.72 447.1 605. 633./ 791.

Reference system

Conv. Insulated All Electric House; Heat

Pump (IF-2) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 79 0.0 N A /

Systems compared to reference system

Conv. Insulated All Electric House; Improved

Heat Pump (IF-2) . . . . . . . . . . . . . . . . . . . . . . . 80 10.7 1.67/

PV System, Insulated House; Air-Cooled Si

Arrays ($0.50/W); IF-2. . . . . . . . . . . . . . . . . . . . 81 36.8 7.75/

PV System, Insulated House; Air-Cooled Si

Arrays ($0.50/W), Battery Storage; IF-2. . . . . 82 32.8 12.09/

NA NAI NA 226./ NA 300./ NA 300./ NA 601./ NA

8.21 1.51/ 8.0 8 214./ 230 . 282./ 298 . 282./ 297. 558./ 574.

3.11 6.53/ 12.07 247./ 292 . 304./ 348 . 293./ 340. 524./ 570.

9.31 10.42/ 17.88 268./ 321 . 323./ 376 . 310./ 366. 534./ 589.
PV System, Insulated House; Air-Cooled St

46.3 6.55/ 10.96 5.55/ 10.11

35.8 2.70/ 5.7 1 2.29/ 5.3 6

58.9 12.06/ 18.78 10.18/ 17.17

71.2 5.78/ 9.0 2 5.02/ 8.3 7

238./ 284 . 289. / 335.

202./ 226 . 257./ 281 .

278./ 326. 487./ 534.

254./ 279. 480. / 505.

83

84

85

86

87

88

89

89/198

Arrays ($0.50/W); IF-2. . . . . . . . . . . . . . . .

. PV System, lnsulated House; Air-Cooled Thin-

. . Film Arrays ($O.1O/W); IF-2 . . . . . . . . . . . . . . .

PV Cogeneration, Insulated House; One-Axis

Concentrator With Si Cells ($15/W Cells),

,

Multitank Low-Temp. Storage; Improved

IF-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

PV System, Insulated House; Heat Engine,

Air-Cooled Silicon Arrays ($0.50/W), LowTemp. Storage; IF-2. . . . . . . . . . . . . . . . . . . . .

Reference system

Conv. All Electric House; Resistance Heat

and Window A/C (SF-3). . . . . . . . . . . . . . . . . .

Systems compared to reference system

Conv. All Electric House; Resistance Heat

and Window A/C, 65/85 Thermostat (SF-3). .

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; SF-4 . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; SF-4 . . . . . . . . . . . . . . . ., . .

.—

Reference system

Conv. Insulated All Electric House;

Resistance Heat and Window A/C (IF-3). . . .

Systems compared to reference system

Conv. Insulated House; Resistance Heat and

Window A/C, 65/85 Thermostat (IF-3 )

302./ 392 . 343.1 432. 317./ 410. 482./ 57 5

178. / 230. 224./ 276 . 212. / 266. 255./ 308.

0.0 NA/ NA NA/ NA 307./ NA 421./ NA 421./ NA 883./ NA

2.5

43.9

43.9

412. / 421. 865./ 874.

363./ 425. 651./ 713.

329. / 372. 617.1 659.

-.00/ 9.38 -.00/ 9.38

6.54/ 10.12 5.53/ 9.26

4.14/ 6.60 3.50/ 6.05

301./ 310. 412. / 421.

309./ 369. 380./ 440.

269./ 310. 340./ 381. ——

90 NA/ NA NA/ NA 240./ NA 326./ NA 326./ NA 676./ NA

91

0.0

3.5

0 0

9.2

20.2

12.1

12.1

25.3

25.3

. ——

-.00/ 11.10 -.00/ 11.10 234./ 245 . 318./ 328 . 318./ 328. 658./ 66 8

FORT WORTH SINGLE FAMILY

Reference system

Conv. Gas Heat, Hot Water, and Central Electric AIC (SF-7) . . . . . . . . . . . . . . . . . . . . . . . . . . 92 NA/ NA NA/ NA 132./ NA 188./ NA 188./ NA 326./ NA

Systems compared to reference system

Conv. Improved Gas Heat, Hot Water, and

Central Electric A/C (SF-1) . . . . . . . . . . . . . . .

Conv. Insulated HO U Se; Gas Heat. Hot Water,

and Central Electric A/C (IF-1) . 

Solar Hot Water Flat-plates (1977 Prices);

SF-1 . . . . . . . 

Solar Hot Water; Flat-plates (Future price);

SF-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Heating; Fiat-plates (1977 Prices), LowTemp. Storage; SF-1 . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-plates (Future Price), LowTemp. Storage; SF-1 . . . . . . . . . . . . . . . . . . . .

93 .87/ 7.7 0 .76/ 7.60 127./ 141. 177. / 191. 176. / 190. 309./ 323.

94

95

-.21/ 2.8 1 -.35/ 2.6 9 115./ 129. 158./ 172. 158./ 171. 277./ 291.

8.20/ 16.89 6.91/ 15.79 146./ 169. 193. / 216. 189. / 213. 320./ 344.

5.83/ 13.39 4.91 / 12.60 1 39./ 160. 186./ 207. 184. / 205. 315./ 33 5 95/5

96

96/127

13.17/ 21.60 11.16/ 19.88 189. / 236. 227. / 274. 215. / 264. 337./ 386

8.57/ 14.87 7.25/ 13.74 163./ 198, 201. / 236. 193. / 230. 315./ 351.
Effective cost of solar Levelized monthly cost

Summary description of system Table Percent energy (¢/kWh) of energy service

numbe r sola r No 200/0 Projection 1 Projection 2 Projection 2 Projection 3

credits ITC No credits No credits 20%ITC 20%lT C

Reference system

Conv. Gas Heat, Hot Water, and Absorption

A/C (SF-7) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 97 0.0 NA/ NA NAI NA 134./ NA 206./ NA 206./ NA 321./ NA

Systems compared to reference system

Conv. Insulated House; Gas Heat, Hot Water,

and Absorption A/C (IF-7) . . . . . . . . . . . . . . . . 98 19.4 -.63/ 3.0 2 -.68/ 2.9 8 116./ 133. 173./ 190 . 173./ 190. 273./ 290.

Solar Heating and Cooling; Flat-Plates (1977

Prices); Low-Temp. Storage; SF-7 . . . . . . . . . 99 47.7 9.45/ 15.43 7.99/ 14.19 208./ 277. 242./ 311 . 225./ 297. 306./ 378.

Solar Heating and Cooling; Flat-Plates (Future

Price); Low-Temp. Storage; SF-7 . . . . . . . . . . 99/143 47.7 6.00/ 10.37 5.07/ 9.5 7 168./ 219. 202./ 253 . 191 ./ 244. 272./ 324.

Reference system

Conv. All Electric House; Heat Pump (SF-2) .

Systems compared to reference system

Conv. All Electric House; Improved Heat

Pump (High Cost) (SF-2) . . . . . . . . . . . . . . . . .

Conv. All Electric House; Improved Heat

Pump (SF-2) . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-Plates (1977 Prices);

SF-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-Plates (Future Price);

SF-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; SF-2 . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; SF-2 . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; SF-2 . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; SF-2 . . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Si Arrays ($0.50/W);

SF-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Thin-Film Arrays

($O.1O/W); SF-2 . . . . . . . . . . . . . . . . . . . . . . . .

PV Cogeneration; One-Axis Concentrator With

Si Cells ($15/W Cells), Multitank Low-Temp.

Storage; SF-2 . . . . . . . . . . . . . . . . . . . . . . . . . .

100

101/125

101

102

102/1 50

103

103/152

104

104/1 54

105

106

107

0.0

15.0

15.0

22.3

22.3

26.5

26.5

34.9

34.9

64.9

45.5

58.4

NA/ NA

6.16/ 11.89

1.55/ 5.6 1

3.54/ 7.5 3

2.50/ 6.0 1

6.26/ 11.09

4.16/ 8.0 3

7.65/ 12.70

4.98/ 8.7 9

6.78/ 10.79

2.63/ 5.0 3

17.96/ 27.33

NAI NA

5.59/ 11.41 

1.41/ 5.4 9

2.98/ 7.0 6

2.11/ 5.67

5.31/ 10.28

3.53/ 7.4 9

6.48/ 11.70

4.21/ 8.1 3

5.70/ 9.8 6

2.20/ 4.6 6

15.12/ 24.91

179./ NA

186./ 210.

166./ 183.

173./ 198.

166./ 188.

192./ 227.

176./ 205.

209./ 258.

183./ 220.

238./ 311./

165./ 195.

401./ 553.

233./

232./

213./

215./

209./

232./

216./

245./

219./

266./

199./

427. /

NA

256.

229.

240.

230.

268.

245.

294.

256.

339.

230.

579.

233./ NA 451./ NA

229./ 254.

212./ 229.

212./ 237.

206./ 228.

225./ 262.

212./ 241.

234./ 285.

212./ 250.

247./ 322.

194./ 225.

380./ 540.

417./ 441.

399./ 416.

384./ 409.

379./ 401.

388./ 425.

375./ 405.

380./ 431.

358./ 396.

362./ 437.

335./ 366.

484./ 643.
Reference system

Conv. Insulated All Electrlc House; Heat

Pump (IF-2) . . . . 108 0.0 157./ NA 203./ NA 203./ NA 387./ NA

11.4

50.3

40.2

36.6

50. 3

38.6

58.9

51.4

70.5

NA/ NA NA/ NA

Systems compared to reference system

Conv. Insulated All Electrlc House; Improved

Heat Pump (IF-2) . . . . . . . . . . . . . . . . . . . .

PV System, Insulated House; Air-Cooled Si

Arrays ($ I/W); Improved IF-2 . . . . . . . . . . . . .

PV System, Insulated House; Air-Cooled ThinFilm Arrays ($0.50/W); IF-2 . . . . . . . . . . . . . .

PV System, Insulated House; Air-Cooled ThinFilm Arrays ($0.50/w), Battery Storage; IF-2

PV System, Insulated House; Air-Cooled Si

Arrays ($0.50/W); Improved IF-2 . . . . . . . , . .

PV System, Insulated House; Air-cooled ThinFilm Arrays ($0.1()/W); IF-2 . . . . . . . . . . . . . . .

PV System, Insulated House; One-Axis Concentrator With Si Cells ($0.15/W Cells);

Multitank Low-Temp. Storage; Improved

IF-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Conv. Engine Cogeneration, Insulated House;

Stirling Engine (Low Eff.), Direct Drive Heat

Pump, Gas Hot Water, Low-Temp. Storage,

No Grid Connect Ion (IF-9). ., . . . . . . . .

PV Heat Engine System, Insulated House; AlrCooled Thin-FiIm Arrays ($0.50/W), LowTemp. Storage; IF-2 ... ., .

1 50. / 167.

234./ 306 .

186. / 232.

208./ 263 .

181./ 229.

143. / 169.

191. / 208.

261./ 333 .

217./ 263 .

238.1 293.

208./ 256 .

173./ 199 .

190./ 207. 355./ 372.

242.1 317. 352./ 427.

207./ 254. 333./ 380.

226./ 282. 347./ 403.

198./ 247. 308./ 357.

170. / 196. 294./ 320.

1.79/ 8.3 1

10.38/ 16.54

6.89/ 11.79

10.54/ 16.97

5.92/ 9.9 8

2.51/ 5.3 7

1.63/ 8.1 7

8.76/ 15.16

5.81I 10.86

9.08/ 15.72

109

11 2/172

110

111

112

113

5.01/ 9.2 1

2.13/ 5.0 5

114 11.77/ 18.40 9.93/ 16.83 258./ 348 . 278./ 369 . 253./ 348. 337./ 432.

150./ 173. 183./ 207.

171 ./ 227. 192./ 247.

115 2.96/ 4.8 9

5.82/ 9.1 0

2.80/ 4.7 5

5.07/ 8.4 6

115./ 138.

161./ 215.

152. / 175.

116 184./ 237 .

Reference system

Conv. All Electric House; Resistance Heat

and Window AIC (SF-3) . . . . . . . . . . . . . . . . . . 117 0.0 NA/ NA NA/ NA 182./ NA 245./ NA 245./ N A 502./ N A

Systems compared to reference system

Conv. All Electric House; Resistance Heat

and Window A/C, 65/85 Thermostat (SF-3). 118

Conv. Insulated All Electric House;

Resistance Heat and Window AIC (IF-3). . . . 119

Conv. Insulated All Electric House;

Resistance Heat and Window AIC, 65/85

Thermostat (IF-3) . . . . . . . . . . . . . . 120

8.6 -.00/ 3.1 7 -.00/ 3,1 7 169./ 178. 227./ 236 . 227./ 236. 462./ 471.

27.0 .15/ 1.28 .08/ 1.22 143./ 153. 190./ 200 . 189./ 199. 379./ 389.

34.4 .12/ 1.0 0 .06/ .96 132./ 142. 174./ 184 . 174./ 184. 346./ 356.

OMAHA SINGLE FAMILY

Reference system

Conv. Gas Heat, Hot Water, and Central Electric A/C (SF-1). . . . . . . . . . . . . . . . . . . . . . . . . . 121 0.0 NAI NA NAI NA 125./ NA 180./ NA 180./ NA 302./ NA
Effective cost of solar Levelized monthly cost

Summary description of system Tabl e Percent energy (¢/kWh) of energy service

numbe r solar N o 2 0 % Project Ion 1 Projection 2 Projection 2 Projection 3

credits ITC No credits No credits 20% ITC 20% ITC

Systems compared to reference system

Conv. Improved Furnace, Gas Hot Water, and

Central Electric A/C (SF-1) . . . . . . . . . . . . . . . 122 11.9

Conv. Gas Heat, Hot Water, and Central Electric A/C, 65/85 Thermostat (SF-1). . . . . . . . . . 123 10.0

Solar Hot Water; Flat-Plates (1977 Prices);

SF-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 124 10.4

Solar Hot Water; Flat-Plates (Future Price);

SF-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125 10.4

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; SF-1 . . . . . . . . . . . . . . . . . . . . 126 24.0

Solar Heating; Fiat-Plates (Future Price), LowTemp. Storage; SF-1 . . . . . . . . . . . . . . . . . . . . 127 24.0

.77/ 6.21

-.00/ 6.08

9.04/ 19.03

6.42/ 15.16

14.00/ 22.72

9.40/ 15.98

.67/ 6.1 2 121./ 136. 169. / 185. 169. / 184. 284./ 299.

-.00/ 6.0 8 115./ 129, 167. / 181. 167. / 181. 272./ 286.

7.62/ 17.81 142. / 166, 191. / 215. 188. / 213. 303./ 328.

5.41/ 14.30 135.1 157. 185./ 206. 182./ 204. 298./ 320.

11.98/ 21.00 191./ 240. 233./ 282. 221.1 272. 330./ 381.

8.07/ 14.85 165./ 202. 207./ 244. 199./ 237. 308./ 346.

Reference system

Conv. Insulated House; Gas Heat, Hot Water,

and Central Electric A/C (IF-1) . . . . . . . . . . . . 128 0.0 NA/ NA NA/ NA 111./ NA 154./ NA 154./ NA 261./ NA

Systems compared to reference system

Conv. Insulated House; Improved Gas Heat,

Hot Water, and Central Electric A/C (IF-1) 129 11.3 .80/ 8.4 0 .70/ 8.3 1 108./ 124. 146./ 161.

Conv. Insulated House; Gas Heat, Hot Water,

146./ 161. 248./ 264.

and Central Electric A/C, 65/85 Thermostat

(IF-1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 130 11.4 -.00/ 7.1 6 -.00/ 7.1 6 103./ 117. 142./ 156. 142./ 156. 234./ 249.

Reference system

Conv. Oil Heat and Central Electric A/C (SF-5) 131 0.0 NA/ NA NA/ NA 204./ NA 263./ NA 263./ NA 522./ NA

Systems compared to reference system

Conv. Improved Oil Heating, Gas Hot Water,

and Central Electric A/C (SF-5) . . . . . . . . . . . 132 13.0 .61/ 5.7 9 .53/ 5.7 2 186./ 204. 237./ 255 . 237./ 255. 461./ 479.

Conv. Oil Heat and Central Electric A/C, 65/85

Thermostat (SF-5). ., . . . . . . . . . . . . . . . . . . . . 133 8.7 -.00/ 7.3 0 -.00/ 7.3 0 195./ 212. 249./ 267 . 249./ 267. 492./ 509.

Solar Hot Water; Flat-Plates (1977 Prices);

SF-5 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 134 11.4 7.23/ 16.16 6.09/ 15.19 209./ 236. 261./ 288 . 257./ 285. 486./ 513.

Solar Hot Water; Flat-Plates (Future Price);

SF-5 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 135 11.4 5.14/ 13.07 4.33/ 12.38 202./ 227. 254./ 279 . 252./ 276. 480./ 505.

Solar Heating; Flat-Plates (1977 Prices); SF-5 . 136 26.2 11.55/ 18.97 9.941 17.60 244./ 297. 288./ 340 . 277./ 331. 466./ 520.

Solar Heating; Flat-Plates (Future Price); LowTemp. Storage; SF-5 . . . . . . . . . . . . . . . . . . . 137 26.2 7.87/ 13.58 6.81/ 12.68 219./ 259. 262./ 302. 255./ 296. 444./ 485.
Reference system

Conv. Insulated House; Oil Heat and Central

Electric A/C (IF-5). . . . . . . . . . . . . . . . . NA/ NA

.56/ 7.3 7

-.00/ 8.0 6

125./ NA

121./ 138.

116. / 133.

—.

127./ NA

211./ 281

171./ 223.

173./ NA

162. / 180.

160. / 177.

188./ NA

245./ 315 .

205./ 256 .

173./ NA 285./ NA

162./ 179. 268./ 286.

160./ 177. 258./ 274.

138 0.0 NA/ NA

Systems compared to reference system

Conv. Insulated House; Improved Oil Heating,

Hot Water, and Central Electric A/C (IF-5)

Conv. Insulated House; Oil Heat and Central

Electric A/C, 65/85 Thermostat (IF-5). . . . . . .

.64/ 7.4 4

-.00/ 8.0 6

12.6

10.2

139

140

Reference system

Conv. Gas Heat, Hot Water, and Absorption

A/C (SF-7) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.0 NA/ NA NA/ NA

8.43/ 15.04

5.351 10.17

——.

NA/ NA

188./ NA 297./ NA

228./ 301. 313./ 38 5

194./ 247. 279./ 332.

141

Systems compared to reference system

Solar Heating and Cooling; Flat-Plates (1977

Prices), Low. Temp. Storage; SF-7 . . . . . . . . .

Solar Heating and Cooling; Flat-Plates (Future

Price); Low-Temp. Storage; SF-7 . . . . . . . . . .

9.97/ 16.35

6.33/ 11.00

44.4

44.4

142

143

Reference system

Conv. Insulated House; Gas Heat, Hot Water,

and Absorption A/C (IF-7) . . . . . . . . . . . . . . . .

Systems compared to reference system

111./ NA 158./ NA 158./ NA 254./ N A

244./ 334 . 276./ 365. 251./ 345. 280./ 374.

144 0.0 NAI NA

Solar Engine System, Insulated House; ORCS

and One-Axis Tracker (Future Design),

High-Temp. Oil Storage; IF-7 . . . . . . . . . . . . 145 33.0 27.39/ 41.58 23.57/ 38.32

Reference system

Conv. All-Electric House; Heat Pump (SF-2) . . 146 0.0 NA/ NA NA/ NA 190./ NA 249./ NA 249./ NA 490. / NA

Systems compared to reference system

Conv. Improved Heat pump (SF-2). . . . . . . . .

Conv. All Electric House; Heat Pump, 65/85

Thermostat (SF-2). . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-Plates (1977 prices);

SF-2 . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-plates (Future price);

SF-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

222./ 238.

237./ 251.

237./ 262.

232./ 253.

250.1286.

238./ 267.

260./ 310.

237./ 275.

365./ 490.

277./ 352.

18.1 424. / 440.

7.0

16.8

16.8

20.5

20.5

29.1

29.1

53.6

53.6

.98/

-.00/’

3.90/

2.76/

6.56/

4.48/

7.63/

4.97/

12.61/

6.83/

3.65

5.96

8.18

6.50

11.57

8.54

12.60

8.69

19.33

10.83

.89/

-.00/

3.29/

2.33/

5.58/

3.80/

6.47/

4.20/

10.60/

5.74/

3.57

5.96

7.65

6.12

10.73

7.96

11.60

8.04

17.61

9.90

1 73. / 189. 223./

237./

241./

234./

257./

243./

271./

245./

401./

239.

251.

265.

255.

292.

271.

319.

281.

521,

147

148

149

150

151

152

153

154

155

156

.

.

. .

. .

181./ 195.

215.

462./ 476.

191./ 442./ 467.

184./ 205. 437./ 458.

Solar Heating; Using Flat-plates (1977 Prices),

Low-Temp. Storage; SF-2 . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; SF-2 . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; SF-2 . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Price); LowTemp. Storage; SF-2 . . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Si Arrays ($1/W); SF-2.

PV Cogeneration; Air-Cooled Si Arrays

($0.50/W); SF-2 . . . . . . . . . . .

209./ 243. 447./ 483.

195./

227./

435./ 464.

438./ 488.

222.

275.

416./ 453.

517./ 643.

201./

363./

237.

484.

259./ 331. 297./ 369. 430./ 505.
I I I Effective cost of solar I Levelized monthly cost

Summary description of system Percent energy (¢/kWh) of energy service

sola r

T

No 2 0 % Projection 1 Projection 2 Projection 2 Projection 3

credits ITC No credits No credits 20%lT C 20% ITC

Systems compared to reference system—Continued

PV Cogeneration; Water-Cooled Si Arrays

($1/w), Multitank Low-Temp. Storage; SF-2.

PV Cogeneration; Water-Cooled Si Arrays

($0.50/w), Multitank Low-Temp. Storage;

SF-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Thin-Film Arrays

($0.30/W); SF-2 . . . . . . . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Thin-Film Arrays

($O.1O/W); SF-2 . . . . . . . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Thin-Film Arrays

($O.1O/W), Battery Storage; SF-2 . . . . . . . . . .

PV Cogeneration; One-Axis Concentrator With

Si Cells ($15/W Cells); Multitank Low-Temp.

Storage; SF-2 . . . . . . . . . . . . . . . . . . . . . . . . . .

PV Cogeneration; One-Axis Concentrator With

Si Cells ($15/W Cells), Multitank Low-Temp.

and Battery Storage; SF-2. . . . . . . . . . . . . . . .

PV Cogeneration; One-Axis Concentrator With

Si Cells ($1/W Cells), Multitank Low-Temp.

Storage; SF-2 . . . . . . . . . . . . . . . . . . . . . . . . . .

63.2 15.18/ 23.00

8.64/ 13.36

5.54/ 9.5 6

2.61/ 4.9 4

3.45/ 6.1 8

14.73/ 22.39

15.83/ 23.96

3.93/ 6.3 5

12.78/ 20.94

7.27/ 12.19

4.64/ 8.8 0

2.18/ 4.5 8

2.93/ 5.7 4

12.41 I 20.40

13.37/ 21.86

3.30/ 5.8 2

441./ 607.

303./ 403.

212./ 252.

183./ 213.

189./ 221.

411./ 563.

423./ 579.

200./ 256.

472./ 638.

334./ 434.

259./ 298.

226./ 256.

231./ 263.

441./ 593.

452. / 609.

226./ 282.

157 421./ 594. 547./ 720.

158

159

160

161

63.2

29.2

37.9

35.2

305./ 409.

250./ 291.

221. / 251.

225./ 258.

431./ 535.

438./ 478.

395./ 426.

397./ 430.

162 59.4 395./ 553. 517./ 675.

163 57.5 405. / 568. 526./ 690.

164 69.3 21 1./ 270. 317./ 376.

Reference system

Conv. Insulated All Electric House, Heat

Pump (IF-2 ) 165 0.0 NA/ NA NA/ NA 161./ NA 208./ NA

197./ 212.

193. / 210.

193./ 215.

200./ 233 .

202./ 240 .

284./ 353 .

270./ 341 .

231 ./ 276.

251./ 305 .

208./ NA 399./ NA

Systems compared to reference system

Conv. Insulated All Electric House; Heat

Pump, 65/85 Thermostat (IF-2 )

Conv. Insulated All Electric House; Improved

Heat Pump (IF-2) . . . . . ., .,

Solar Hot Water, Insulated House; Flat-Plates

(Future Price), Low-Temp. Storage, IF-2.

Solar Heating, Insulated House Using FiatPlates (Future Price), Low-Temp. Storage,

I F-2 . . . . .

Solar Heating, Insulated House; Flat-Plates

(Future Price); Low-Temp. Storage; IF-2.

PV System, Insulated House; Air-Cooled S t

Arrays ($ I/W); IF-2 ... . .

PV System, Insulated House; Air-Cooled Si

Arrays ($ I/W); Improved IF-2 ., ... .,

PV System, Insulated House; Air-Cooled Si

Arrays ($0.50/W); IF-2. . . . . . . . . . . . . . .

PV System, Insulated House; Air-Cooled Si

Arrays ($0.50/W), Battery Storage; IF-2. ., . .

166

167

8.0

13.5

22.0

-.00/ 7.3 6

1.31 / 6.15

2.74/ 6.6 7

4.54/ 8.3 6

4.86/ 8.6 3

12.55/ 20.08

9.71/ 15.47

6.88/ 11.75

10.67/ 17.17

-.00/ 7.3 6

1.19/ 6.0 4

2.31/ 6.3 0

3.84/ 7.7 6

4.11/ 7.99

10.54/ 18.36

8.18/ 14.16

5.77/ 10.81

9.17/ 15.89

153./ 168.

152./ 169.

154./ 177.

167./ 200.

171./ 208.

248./ 318.

240./ 311.

196./ 241.

217./ 271.

197./ 212. 375./

193./ 210. 362./

190. / 213. 346./

390.

379.

168 368.

33.9

38.6

36.1

47.9

36.1

32.1

169

170

171

172

173

174

194./ 228. 330./

195./ 233. 323./

265./ 338. 409./

252./ 325. 376./

221./ 267. 364./

239./ 294. 378./

364.

362.

481.

450.

411.

433.
Systems compared to reference system—Continued

PV System, Insulated House; Air-Cooled Si

Arrays ($0.50/W), Improved IF- 2

PV System, Insulated House: Air-Cooled ThinFilm Arrays ($O30/W); Improved IF-2

PV System, Insulated House; Air-Cooled ThinFilm Arrays ($ O. IO/W); Improved IF-2

PV Cogeneration, Insulated House; One-Axis

Concentrator With Si Cells ($15/W Cells),

With Multitank Low-Temp. Storage; improved IF-2 . ... . . . . . . . . . . . . . . . . . . . .

PV Cogeneration, Insulated House; One-Axis

Concentrator With Si Cells ($15/W Cells),

Multitank Low-Temp. Storage; Improved

IF-2. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

PV Cogeneration, Insulated House; One-Axis

Concentrator With Si Cells ($1/W Cells),

Multitank Low-Temp. Storage; Improved

IF-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

PV Cogeneration, Insulated House; One-Axis

Concentrator With Si Cells ($1/W Cells),

Multitank Low-Temp. Storage; IF-2 . . . . . . . .

PV Cogeneration, Insulated House; One-Axis

Concentrator With Si Cells ($1/W Cells),

Multitank Low-Temp. Storage; Improved

IF-2. . . . . . . . . , , ., . . . . . . . . . . . . . . . . . . .

PV Cogeneration, Insulated House; Air-Cooled

Si Arrays ($0.50/w), Diesel Backup, LowTemp. Storage; IF-2. . . . . . . . . . . . . .

PV Cogeneration, Insulated House; Plastic

Dye Concentrator, Multitank Low-Temp.

Storage; IF-2. . . . . . . . . . . . . . . . . . . . .

PV System, Insulated House; Plastic Dye

Concentrator; IF-2 ... , . . . .

Conv. Engine Cogeneration, Insulated House;

Stirling Engine (Low Eff ), Direct Drive Heat

Pump, Gas Hot Water, Low-Temp. Storage

(IF-9). . . . . . . . . . . . . . . ... . . . . . . . . . . . . . . .

4.62/ 8.5 2

3.31/ 7.00

1.97/ 4.65

1 88. /

163. /

1 50. /

234.

193.

175.

218./ 265 .

199./ 228.

183./ 209.

208. / 256.

194./ 224.

180. / 206.

332./ 381.

336./ 367.

317. / 343.

47.9

32.2

37.3

57.4

80.5

43.4

52.1

63.0

72.0

79.7

74.8

56.3

5.48/ 9.2 5

3.91/ 7.5 1

2.321 4.9 5

175

176

177

178

179

180

181

182

183

184

185

186

10.89/ 17.00 9.19/ 15.55 266./ 356. 291./ 381 . 266. / 359. 366./ 460.

14.34/ 21.81 12.09/ 19.89 381./ 536. 397./ 552 . 351./ 512. 416. / 578.

208./ 250 .

210.I 259 .

198. / 242.

198. / 249.

321./ 365.

308./ 358.

5.27/ 9.07

5.381 9.01

4.43/ 8.3 5

4.52/ 8.2 8

178./

183./

220.

232.

4.99/ 8.21

5.39/ 8.38

3.42/ 5.75

3.02/ 5.24

4.23/ 7.56

4.70/ 7.79

2.87/ 5.28

2.53/ 4.82

182. /

161 ./

165. /

234.

216.

212.

205./ 257.

178./ 234.

185./ 233,

191./ 234.

192. / 246.

165. / 223.

174. / 223.

181 ./ 225.

285./ 340.

182. / 239.

256./ 306.

165./ 208 . 285. / 329.

2.49/ 4.07 2.35/ 3.95 106. / 129. 133. / 156, 131./ 155. 157./ 180.

—.—

Reference system

Conv. All Electric House; Resistance Heat

and window A/C (SF-3) . . . . . . . . . . . . . . . . . 187 0.0

Systems compared to reference system

Conv. All Electric House; Resistance Heat

and Window A/C, 65/85 Thermostat (SF-3). . 188 4.7

Solar Heating: Flat-plates (1977 Prices), LowTemp. Storage; SF-4 . . . . . . . . . . . . . . . . . . . . 191 32.7

Solar Heating, Flat-Plates (Future Price), LowTemp. Storage; SF-4 . . . . . . . . . . . 192 32.7

NA/ NA NAI NA

-.00/ 5.17 -.00/ 5.1 7

5.37/ 8.5 9 4.55/ 7.8 9

3.46/ 5.79 2.93/ 5.3 4

206./ NA 277./ NA 277./ NA 570./ NA

198./ 208. 267./ 277 . 267./ 277 547/ 557

226./ 270 277./ 320 265./ 311 471./ 517

200./ 232. 251./ 282. 243, / 276 449 / 482.
Effective cost of solar Levelized monthly cost

Summary description of system Table Percent energy (¢/kWh) of energy service

numbe r

T

sola r N o 20% Project Ion 1 Projection 2 Project Ion 2 Project Ion 3

credits ITC No credits No credits 20% ITC 20% ITC

Systems compared to reference system—Continued

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; SF-3 . . . . . . . . . . . . . . . . . . . . 197 38.3 6.23/ 9.7 6 5.27/ 8.9 4 243./ 300 . 290./ 347.

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; SF-3 . . . . . . . . . . . . . . . . . . . . 198 38.3 3.95/ 6.4 1 3.34/ 5.8 9 207./ 246 . 254./ 293.

100-Percent Solar Heating; Insulated House;

Flat-Plates (1977 Prices), Community

Seasonal Low-Temp. Storage; SF-2. . . . . . . . 199 76.4 6.79/ 10.21 5.66/ 9.2 5 299./ 408. 321. / 430.

100-Percent Solar Heating; Flat-Plates (Future

Price), Central Electric A/C, Community

Seasonal Aquifer Storage; SF-2. . . . . . . . . . 200 76.4 4.15/ 6.2 7 3.521 5.7 2 215./ 282. 237./ 304 .

Reference system

Conv. Insulated All Electric House;

Resistance Heat and Window A/C (IF-3). . . . 201 0.0 NA/ NA NA/ NA 159./ NA 211./ NA

Systems compared to reference system

Conv. Insulated All Electric House;

Resistance Heat and Window A/C, 65/85

Thermostat (IF-3) . . . . . . . . . . . . . . . . . . . . . . . 202 5.9 -.00/ 6.5 4 -.00/ 6.5 4 152. / 163. 201 ./ 213.

275./ 334. 466. / 525.

244./ 285. 435. / 476.

285. / 399. 375. / 490

217. / 287. 307./ 377

211./ NA 423./ NA

201./ 213, 403. / 414.

OMAHA SINGLE FAMILY

TIME-OF-DAY RATES

Reference system

Conv. All Electric House (SF-3); Marginal Electric Rates. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . T187 0.0 NA/ NA NA/ NA

Systems compared to reference system

Conv. Off-Peak Electric Heating; Window A/C,

Low-Temp. Storage (SF-4). . . . . . 189 -.7 -79.79/ ● ’*’*”

-62.11 / ● **** ●

Conv. Off-Peak Electric Heating and Chilling;

Low-Temp. Thermal and Cold Storage (SF-4). 190 3

● .**.*, ,.,..,

-. ● ***.., .****,

Solar Off-Peak Heating; Flat-Plates (1977

Prices), Low-Temp. Storage; SF-4 . . . . . ., 193 32.3 6.32/ 10.04 5.31/ 9.18

Solar Off-Peak Heating; Flat-Plates (Future

Price), Low-Temp. Storage; SF-4 . . . . . . . 194 32.3 4.39/ 7.22 3,67/ 6.6 0

Solar Heating and Cooling; Flat-Plates (1977

Prices), Low-Temp. Thermal and Cold

Storage; Off-Peak Electric Backup Heating

and Chilling . . . . . 195 32.7 9.71/ 15.03 8.241 13.77

Solar Off-Peak Heating and Cooling; FlatPlates (1977 Prices), Low-Temp. Storage;

SF-4 . . . . . . . . . . . . . . . . . . . . ... ., . . . . . . 196 32.7 7.80/ 12.24 6.62/ 11.23

278./ N A

218./ 241 .

236./ 278 .

246./ 296.

220./ 258.

268./ 341.

242./ 303.

278./ N A

218./ 241 .

236./ 278 .

246./ 296 .

220./ 258 .

268./ 341 .

242./ 303 .

278./ NA 278./ N A

213./ 237. 213./ 237.

226./ 270. 226./ 270.

232. / 284. 232./ 284.

210./ 250. 210./ 250.

248./ 324. 248.1 324.

226./ 289. 226./ 289.
ALBUQUERQUE HIGH RISE (196 UNITS)

Reference system

Conv. Central Electric Chilled-Water System

With Fan Coil Units and a Central Gas

Boiler (HR-1) . . . . . . . . . . . . . . . . . . . . . . . . . 203

Systems compared to reference system

Solar Hot Water; Flat-Plates (1977 Prices);

HR-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 204

Solar Hot Water; Flat-Plates (Future Prices);

HR-1 . . . . . . . . . . . . . . . . ... . . . . . . . . . 204/278

Solar Heating; l-Cover Pond, Seasonal

Aquifer Storage; HR-1 . . . . . . . . . . . . . . . . . . . 205

PV System; Air-Cooled Si Arrays ($1/W), Battery Storage; HR-1 ., , . . . . 206

PV System; Air-Cooled Si Arrays ($0.50/W);

HR-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . 207

PV System; Air-Cooled Si Arrays ($ I/W); HR-1 207/281

PV System; Air-Cooled Si Arrays ($0.50/W),

Battery Storage; HR-1 . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Thin-Film Arrays

($0.30/W); HR-1 . . . . . . . . . . . . . . . . . . . . . . . . .

Reference system

Conv. Central Gas Boiler and Absorption

Chilling, Two-Pipe System to Fan-Coil Units

(HR-7) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Systems compared to reference system

PV System; Two-Axis Concentrator With

GaAs Cells (Low Price), Battery and Multitank Low-Temp. Storage; HR-8 . . . . . . . . . . .

PV System; Two-Axis Concentrator With

GaAs Cells (Low Price), Battery and Multitank Low-Temp. Storage; HR-7 . . . . . . . . . . .

PV System; Two-Axis Concentrator With

GaAs Cells (Low Price), iron-REDOX Battery

and Multitank Low-Temp. Storage; HR-7 . . .

PV System; Two-Axis Concentrator With

GaAs Cells (Low Price), iron-REDOX Battery

and Multitank Low-Temp. Storage; HR-7

100-Percent Solar PV System; Two-Axis Concentrator With GaAs Cells (Low Price), lronREDOX Battery and Multitank Low-Temp.

Storage; HR-7 . . . . . . . . . . . . . . . . . . . . . . . . . .

PV System; Two-Axis Concentrator With

GaAs Cells (Low Price), Battery and Multitank Low-Temp. Storage; HR-7 . . . . . . . . . . .

Conv. Engine Cogeneration; Gas-Fired

Diesel/ORCS Engine/Generator and LowTemp. Storage; HR-8. . . . . . . . . . , . . . . . . . . .

PV System; Two-Axis Concentrator With

GaAs Cells (Low Price), Multitank LowTemp. Storage; HR-7 . . . . . . . . . . . . . . . . . . . .

208

209

210

211

212

213

214

215

216

217

218

0.0

8.1

8.1

26.4

45.7

51.1

51.1

45.7

11.7

.—

NA/ NA

12.20/ 18.90

7.61/ 13.28

8.45/ 11.17

21.56/ 26.53

8.47/ 11.05

15.28/ 19.38

12.55/ 15.69

26.18/ 34.42

NA/ NA

9.05/ 17.55

5.66/ 12.45

6.61/ 10.38

16.38/ 24.32

6.23/ 10.09

11.26/ 17.67

9.57/ 14.42

19.68/ 31.65

51./

58.I

54./

65./

136./

84.I

117./

96./

78./

—

NA

63.

59.

72.

158.

96.

138.

110.

88.

71./

76./

72./

77.I

152./

100.I

134./

112.I

98.I

NA

81.

77.

84.

174.

113.

154.

126.

107.

71./N A

74./ 80

71./ 76

-.72./ 82

129./ 165

89.I 108

114./ 146

99./

90./

21

04

129/ NA

129./ 136

126./ 132

122./ 132

170./ 205

132./ 151

157.I 189.

140./ 161

144./ 157 —

0.0 NAI NA NA/ NA 49./ NA 73./ NA 73./ NA 121./ NA

74.9

97.1

106.8

06.6

00.0

21.4

37.7

73.5

4.31 I 5.68

5.371 67 6

6.66/ 8.2 7

8.35/ 10.19

9.67/ 11.75

6.62/ 8.1 3

11.51/ 14.44

5.03/ 6.52

3.26/ 5.2 3

4.14/ 6.24

5.16/ 762

6.53/ 9.4 1

7.58/ 10.86

5.15/ 7.5 0

8.97/ 13.35

3.85/ 6.0 2

85. /

101./

87./

106. /

1 14. /

97. /

78. /

61. /

95

115.

105.

126.

135.

116.

90.

72

100. /

1 14. /

87.1

106./

114./

97. /

99 I

69. /

110.

128.

105.

126.

135.

116

111

81.

92. / 107

102. / 123.

71. / 98

86./ 118

92./ 126.

79. / 108

89. / 106

60. / 77.

153./

155. /

71. /

86./

92./

79./

109./

69./

168.

176.

98.

118

126.

108

126

85
I I I Effective cost of solar I Levelized monthly cost

Summary description of system Table Percent energy (¢/kWh) of energy service

numbe r sola r N o 2 0 % Project Ion 1 Project Ion 2 Projection 2 Projection 3

credits ITC No credits No credits 20% ITC 20% ITC

Systems compared to reference system—Continued

Solar Engine; LT ORCS and 2-Cover Pond,

Seasonal Aquifer Storage, HR-7 . . . . . . . . . . 219

Solar Engine; LT ORCS and 2-Cover Pond,

Seasonal Aquifer Storage, HR-7 . . . . . . . . . . 220

Solar Engine Cogeneration; Two-Axis Dish

With High Eff. Stirling Engine/Generator,

Gas Backup, and Low-Temp. Storage; HR-8 221

Solar Engine Cogeneration; Two-Axis Dish

With Low Eff. Stirling Engine/Generator,

Gas Backup, and Multitank High- and LowTemp. Storage; HR-8 . . . . . . . . . . . . . . . . . . . . 222

Solar Engine Cogeneration; Two-Axis Dish

With Low Eff. Stirling Engine/Generator,

Gas Backup, and Muititank High- and LowTemp. Storage; HR-7 . . . . . . . . . . . . . . . . . . . . 223

Solar Engine Cogeneration; Two-Axis Dish

With High Eff. Stirling Engine/Generator,

Gas Backup, and Multitank Low-Temp.

Storage; HR-8. ., . . . . . . . . . . . . . . . . . . . . . . . 224

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engines (High Eff.), Battery and

High- and Low-Temp. Storage; Gas Backup;

HR-7 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 225

100-Percent Solar Engine Congelation; TwoAxis Dish, Stirling Engine (High Eff.) Battery and High- and Low-Temp. Storage;

HR-7 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 226

100.0

100.0

66.9

71.5

76.4

81.4

98.4

100.0

15.95/

11.19/

4.51/

6.01/

7.31I

6.53/

9.25

3.75

5.56

7.49

9.00

8.02

11.39/ 14.54

12.25/ 15.51

12.35/

8.49/

3.78/

4 77/

5.81 I

5.23/

7.72

2.60

5.25

6.97

8.36

7.46

8.26/ 13.20

8.96/ 14.11

Reference system

Conv. All Electric System; Central Electric

Chilled-Water System and Fan Coil Units

With Resistance Heaters (HR.2) . . . . . . . . . . 227 0.0 NAI NA NA/ NA

Systems compared to reference system

Solar Hot Water; Flat-Plates (1977 Prices);

HR-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 228 19.3 3.35/ 5.0 7 2.48/ 4.7 1

Solar Heating; Flat-Plates (Future Price); HR-2 228/322 19.3 2.09/ 3.5 3 1.55/ 3.30

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; HR-2 . . . . . . . . . . . . . . . . . . . . 229 31.4 4.45/ 6.0 5 3.29/ 5.5 5

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; HR-2 . . . . . . . . . . . . . . . . . . . . 229/324 31.4 2.80/ 4.0 3 2.07/ 3.7 2

Solar Heating; Flat-Plates (1977 Prices),

Seasonal Low-Temp. Storage; HR-2 . . . . . . . 230 52.6 5.55/ 7.4 2 3.87/ 6.7 0

Solar Heating; Flat-Plates (Future Price),

Seasonal Low-Temp. Storage; HR-2 . . . . . . . 2301328 52.6 4.30/ 5.89 2.95/ 5.3 2

179. /

1 30./

56./

67./

79./

75./

1 30. /

1 40. /

213.

156.

63.

78.

92.

87.

162.

174.

84./

87./

84. /

95./

87, /

85./

75. /

1 79. /

1 30. /

67./

77. /

87./

81. /

131./

1 40, /

213.

156.

74.

88.

100.

93.

163.

174.

141. / 197.

102. / 144.

62./ 72.

68./ 84.

75./ 95.

70./ 89.

99./ 149.

107. / 160.

141. / 197.

102. / 144.

72./ 82.

77./ 93

82./ 10 3

76./ 95

99./ 150.

107. / 160.

NA 113./ NA 113./ NA 232./ NA

92. 11 4./ 119, 112. / 118. 220./ 227.

88. 1 10. / 115. 109. / 114. 218. / 223.

102. 1 20. / 128. 115. / 125 218./ 228.

93. 1 13. / 118. 109. / 117. 212./ 220.

99. 97. / 112. 84. / 106. 134. / 156.

88. 87./ 100 . 77 I 95. 126. / 145.

A

●
Solar Heating; Flat-Plates (1977 Prices),

Cheap Seasonal Low-Temp. Storage; HR-2 .

Solar Heating; Flat-Plates (Future Price),

Seasonal Aquifer Storage; HR-2 . . . . . . . . . .

Solar Heating; I-Cover Pond, Seasonal

Aquifer Low-Temp. Storage; HR-1 . . . . . . . . .

Solar Heating; Two-Axis Concentrator (Med.

Price), Multitank Low-Temp. Storage; HR-2 .

PV Cogeneration; Two-Axis Concentrator

With Si Cells (Med. Price), Multitank LowTemp. Storage; HR.2 ., . . . . . . . . . . . . . . . . . .

PV Cogeneration; Two-Axis Concentrator

With Si Cells (Med. Price) Replaced Every

10 Years, Multitank Low-Temp. Storage;

HR-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

PV System; Two-Axis Concentrator With Si

Cells (Med. Price); HR-2 . . . . . . . . . . . . . . . . .

PV System; Two-Axis Concentrator With St

Cells (Med. Price) Replaced Every 10 Years;

HR-2 . . . . . . . . . . . ... , . . . . . . . . . . . . . . . . . . .

PV Cogeneration; Two-Axis Concentrator

With Si Cells (Med. Price), Multitank LowTemp. Storage; HR-2 . . . . . . . . . . . . . . . . . . . .

PV Cogeneration; One-Axis Concentrator With

Si Cells ($15/W Cells), Multitank Low-Temp.

Storage; HR-2. , . . . . . . . . . . . . . . . . . . . . . . . .

PV Cogeneration; one-Axis Concentrator With

Si Cells ($15/W Cells), Battery and

Multitank Low-Temp. Storage; HR-2 . . . . . . .

PV Cogeneration; Two-Axis Concentrator

With High Eff. Cells, Multitank Low-Temp.

Storage; HR-2 . . . . . . . . . . . . . . . . . . . . . . . . . .

PV System; Two-Axis Concentrator With High

Eff. Cells, iron.REDOX Battery and

Multitank Low-Temp. Storage; HR-2 . . . . . . .

PV Cogeneration; Two-Axis Concentrator

With High Eff. Cells, Multitank Low-Temp.

Storage; Diesel Backup; HR-2 . . . . . . . . . . . . — —

Reference system

Conv. All-Electric System; Resistance Heat,

Window A/C and Individual Electric Water

Heaters (HR-4) . . . . . . . . . . . . . . . . . . . . . . . . .

Systems compared to reference system

PV System; Air-Cooled Si Arrays ($ I/W); HR-4

PV System; Air-Cooled Si Arrays ($0.50/W);

HR-4 . . . . . . . . . . . . . . . . . . . . . . . . . . . ., 

PV System; Air-Cooled Thin-Film Arrays

($0.10/W); HR-4 . . . . . . . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Thin-Film Arrays, Vertical on Wall ($0.10/W); HR-4 . . . . . . . . . . . . . .

231

232

233

234

235

236

237

238

239

240

241

242

243

244—.

245

2461349

246

247

248

--- ..—_—

52.6

52.6

51.6

3 0 7

37.1

37.1

6.2

6.2

54.3

63.4

62.9

101.1

96.3

7 8 7

0.0

36.0

36.0

25.2

——6.3

4.11/ 5.43

2.70/ 3.70

1.91/ 2.60

3.69/ 5.0 8

4.13/ 5.54

6.85/ 7.96

22.59/ 30.53

38.15/ 44.34

5.28/ 6.7 7

10.02/ 12.47

10.29/ 12.77

2.90/ 3.6 9

3.08/ 3.9 2

5.18/ 6.4 0

—

NA/ NA

14.95/ 18.68

8.32/ 10.55

5.37/ 7.0 7

3.63/ 6.3 7

3.00/

1.96/

1.52/

2.79/

3.10/

5.81/

16.99/

32.58/

4.96

3.39

2.43

4.70

5.10

7 5 2

281 4

41.96

3.971 6. 2

7.55/ 11.4

7.77/ 11,69

2.20/ 3.3 9

2.35/ 3.6 0

4.03/ 5.91

NA/ NA

11 .00/ 17.00

6.12/ 9.6 1

3.94/ 6.4 6

2.60/ 5.9 4

74./ 84.

63./ 71.

57. / 62.

91. / 98.

95./ 103.

110./ 116.

102. / 109.

116./ 122.

110./ 122.

164. / 187.

166. / 189.

103./ 115.

1 04. / 116.

81. / 96.

83.1 NA

149./ 168.

11 5./ 127.

95./ 101.

84./ 86.

86 I

75. /

69./

117./

120./

135./

1 30./

145./

1 33. /

1 88. /

189. /

123. /

124. /

92./

96

83.

74.

123.

128

141

138

150.

145.

210.

212

135,

136.

106.

112./ NA

1 73. / 192.

140./ 151.

1 20. / 126

112./ 114

77.I 92

69./ 80

66./ 73.

113./ 121

114./ 125

129.I 138

125./ 135.

139. / 148.

122. / 140

164 / 201.

166. / 202

1 13. / 130.

1 13. / 131.

78./ 100.

112./ NA

153./ 184.

129./ 146

115./ 124

111./ 114

127./ 142

119./ 130

116./ 123,

216./ 224

214./ 225

229./ 239

240./ 250.

254./ 263

214./ 232.

261/ 297

262./ 298.

192./ 210

194. / 211.

88./ 109.

229./ N A

254./ 284.

229./ 247

219.I 228.

223./ 226
Effective cost of solar Levelized monthly cost

Summary descruiption of system Table Percent energy (¢/kWh) of energy service

numbe r sola r N o 20% Projection 1 Projection 2 Project Ion 2 Projection 3

credits ITC No credits No credits 20% ITC 20% ITC

BOSTON HIGH RISE (196 UNITS)

Reference system

Conv. Electric Chilled-Water System With Fan

Coil Units and Central Gas Boiler (HR-1) . . .

Systems compared to reference system

Solar Hot Water; Fiat-Plates (1977 Prices);

HR-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-Plates (Future Price);

HR-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Conv. Engine Cogeneration; Diesel/ORCS, Absorption and Electric Chillers, Low-Temp.

Storage; HR-8. . . . . . . . . . . . . . . . . . . . . , . . . .

249 0.0

250 6.7

250/278 6.7

251 33.5

NA/ NA

16.86/ 27.36

10.55/ 19.63

13.64/ 16.43

NA/ NA 105./ NA 1 55. / NA 155./ NA

155./ 163.

152. / 158.

140./ 153

283./ N A

279./ 287.

276./ 282.

181./ 194.

12 50/ 25.50

7.83/ 18.47

11 .44/ 15.49

111./ 118.

107./ 113

102. / 111.

1 57. /

153 /
Reference system

Conv. All Electric System; Resistance Heat,

Individual Window A/C, and Electric Water

Heaters (HR-4) . . . . . . . . . . . . . . . . . . . . . . . . . NA/ NA NA/ NA 169. /

181./

214.I

160.I

NA

192.

233.

167.

231./

231./

264.I

213.I

102.I

108./

104./

96./

128./

120. /

109. /

NA

242

283

220.

NA

117.

111

106.

149

137.

125.

231./ NA

220./ 238

244./ 275

208./ 217

102./ NA

105./ 115

102./ 110

90./ 104

111./ 141.

260 483./ NA

261

261/349

262

0 0

22.5

22.5

1 5 9

Systems compared to reference system

PV System; Air-Cooled Si Arrays ($0.50/W);

HR-4 . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Si Arrays ($1/W); HR-4

PV System; Air-Cooled Thin-Film Arrays

($O.10/W); HR-4 . . . . . . . . . . . . . . . . . . . . . . . . .

FORT WORTH HIGH RISE (196 UNITS)

Reference system

Conv. Central Electric Chilled-Water System

With Fan Coil Units and Central Gas Boiler

for Heat (HR-1) . . . . . . . . . . . . . . . . . . . . ...

12.04/ 15.32

21.62/ 27.08

5.69/ 8.3 8

8.85/ 13.96

15.91/ 24.65

3.64/ 7.51

423/ 441.

448./ 478.

423./ 433.

263

264

264/278

265

266

267

268

NA/ NA NA/ NA 76.I 186./ NA

85./

81./ 

72./

112./

106. /

99./

NA

93.

88.

83.

132.

123.

115.

0 0

6.5

6 5

36.2

5 6 0

63.2

7 0 7

Systems compared to reference system

Solar Hot Water; Flat-Plates (1977 Prices),

HR-1 . . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-Plates (Future Price),

HR-2 . . . . . . . . . . , ... ,

Conv. Engine Cogeneration, Diesel/ORCS, Absorption and Electric Chillers, Low-Temp

Storage; HR-8. . . .

Solar Engine Cogeneration; Two-Ax Is Dish,

Stirling Engine (Low Eff.) High-Temp.

Storage, Gas Backup, HR-8 . . . . . . . . . . . . . .

Solar Engine Cogeneration; TW O- AXIS Dish,

Stirling Engine (Low Eff,), High-Temp. and

Multitank Low-Temp. Storage, Gas Backup;

HR-8 . . . . . ., ., . . . , ., ., . . . . . . . . . . . .

Solar Engine Cogeneration; TW O- AXIS Dish,

Stirling Engine (High Eff.), Multitank LowTemp. Storage, Gas BackUp; HR- 8

Reference system

Conv. All Electric; Central Chilled-water

System and Fan Coil Units With Resistance

Heaters (HR-2) . . . . . . . . . . . . . . . . . . . .

Systems compared to reference system

Solar Hot Water; Flat-Plates (1977 Prices),

HR-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-Plates (Future Price);

HR-2. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; HR-2 . . . . . . . . . . . . . . . . . . .

15.48/ 26.32

9.62/ 19.15

6 67/ 9.1 2

11 51/ 14.67

11 .47/ 2461

7.14/ 18.09

5.29/ 8.5 4

8.86/ 13.54

187. / 197

184 / 192

112./ 126.

126./ 156

7.83/ 11.27

6.53/ 9.41

31. 118./ 143.

107./ 130.

9 74/ 120 8

8 12/ 100 8

106. /

97./ 20 —

269

270

270/322

271

0.0

15.8

15.8

2 2 4

NA/ NA NA/ NA 101./ NA 133./ NA 133./ NA 265./ NA

108./ 115. 138./ 146. 135./ 144. 259./ 268.

106./ 112. 136./ 143. 135/ 142. 258./ 266.

115./ 124. 144./ 154. 139./ 151. 260./ 272.

3.63/ 7.44

3.42/ 6.4 3

4.42/ 8.08

4.87/ 7.97

4.18/ 6.7 6

5.97/ 8.74
Effective cost of solar Levelized monthly cost

Tabl e Percent energy (¢/kWh) of energy service

Summary description of system numbe r sola r

I ! 1 s

N o 2 0 % Projection 1 Projection 2 Projection 2 Project ion 3

credits ITC No credits No credits 20% ITC 20% ITC

Systems compared to reference system—continue

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; HR-2. . . . . . . . . . . . . . . . . . . . 271/324 22.4 3.76/ 6.0 3 2.78/ 5.6 1 107./ 115. 137./ 144.

Solar Heating; Flat-Plates (1977 Prices),

133./ 143. 254./ 264.

Seasonal Low-Temp. Storage; HR-2 . . . . . . . 272 38.6 7.15/ 9.8 9 5.02/ 8.9 8 110./ 127. 129./ 146. 117./ 140. 195./ 218.

Solar Heating; Flat-Plates (Future Price),

Seasonal Low-Temp. Storage; HR-2 . . . . . . . 272/328 38.6 5.43/ 7.7 9 3.75/ 7.0 7 100./ 114. 119./ 133. 109./ 129. 187./ 207.

Solar Heating; Flat-Plates (1977 Prices),

Seasonal Aquifer Storage; HR-2 . . . . . . . . . . 273 38.6 5.57/ 7.6 9 4.08/ 7.0 5 101./ 114. 120./ 133. 111./ 129. 189./ 207.

Solar Heating; Flat-Plates (Future Price),

Aquifer Thermal Storage; HR-2 . . . . . . . . . . . 273/232 38.6 3.57/ 5.2 4 2.61/ 4.8 3 89./ 99. 108./ 118. 103./ 116. 180./ 194.

Reference system

Conv. All Electric System; Resistance Heat,

Individual Window A/C and Electric Water

Heaters (HR-4) . . . . . . . . . . . . . . . . . . . . . . . . . 274 0.0 NAI NA NAI NA 96./ NA 127./ NA 127./ NA 256./ NA

Systems compared to reference system

PV System; Air-Cooled Thin-Film Arrays

($O.1O/W); HR-4 . . . . . . . . . . . . . . . . . . . . . . . . . 275 19.5 4.90/ 7.2 8 3.07/ 6.5 0 101./ 107. 129./ 135 . 124./ 133. 239./ 248.

OMAHA HIGH RISE (196 UNITS)

Reference system

Conv. Central Electric Chilled-Water System

With Fan Coil Units and Central Gas Boiler

(HR-1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Systems compared to reference system

Solar Hot Water; Flat-Plates (1977 Prices);

HR-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-Plates (Future Price);

HR-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Heating; l-Cover Pond, Seasonal

Aquifer Storage; HR-I . . . . . . . . . . . . . . . . . . .

Solar Heating; l-Cover Pond, Seasonal

Aquifer Storage; HR-1 . . . . . . . . . . . . . . . . . . .

PV System; Air-cooled Si Arrays ($1/W); HR-1

PV System; Air-Cooled Si Arrays ($1/W), Battery Storage; HR-1 . . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Si Arrays ($1/W),

Seasonal iron-REDOX Battery Storage;

HR-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Si Arrays ($0.50/W);

HR-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Si Arrays ($0.50/W),

Battery Storage; HR-1 . . . . . . . . . . . . . . . . . . .

276

277

278

279

280

281

282

283

284

285

0.0 NA/ NA NA/ NA 57./ NA 76./ NA 76./ N A 129./ NA

5.2 20.05/ 34.32 14.86/ 32.11 66./ 74. 84./ 92. 82./ 91. 133./ 142.

5.2 12.54/ 25.13 9.31/ 23.75 62./ 69. 80./ 87. 79./ 86. 130./ 138.

34.0 12.80/ 16.48 10.07/ 15.32 94./ 107. 1 05./ 118. 95./ 113. 140./ 158.

34.0 8.30/ 11.06 6.67/ 10.36 78./ 87. 89./ 98. 83./ 96. 128./ 141.

31.3 23.43/ 30.38 17.26/ 27.75 122./ 144. 137./ 160. 1 17./ 151, 153./ 187.

34.3 22.66/ 28.93 16.97/ 26,50 124./ 146. 139./ 161. 118./ 152. 150./ 184.

66.0 33.33/ 41.07 25.061 37.54 257./ 309. 265./ 318 . 209./ 294. 217./ 302.

31.3 13.07/ 17.68 9.64/ 16.21 88./ 103 . 1 04. / 119. 93./ 114. 128./ 150.

34.3 13.71/ 18.06 10.31/ 16.61 92./ 108 . 107./ 122. 95./ 117. 127./ 149.

●

a-.

W

m
PV System, AirCooled Si Arrays ($0 50/W),

Seasonal iron-Redox Battery Storage; HR-1

PV System; Alr-Cooled Th!n-Film Arrays

($0.30/W); HR-1

PV System; Air-Cooled Thin-Film Arrays

($0.10/W), HR-1

PV System; Air-Cooled Thin-Film Arrays

($O.1O/W) Vertical on Wall, HR-1 .,

PV Cogeneratlin; Two-Ax Is Concentrator

With Si Cells, Multitank Low-Temp

Storage; HR-1 ... .

PV Cogeneration; Diesel Backup, TW O- AXIS

Concentrator With High Eff. Cells,

MuItitank Low-Temp. Storage, HR- 2

Solar Engine Cogeneration; One-Axis Tracker,

ORCS Engines, High-Temp. Storage: HR-7

Reference system

Conv. Gas Heat, Hot Water, and Absorption

Chilling (HR-7) . . . . .

Systems compared to reference system

Solar Heating and Cooling, One-Axis Tracker

(Future Design), Low-Temp. Storage; HR-7

Solar Heating and Cooling; One-Axis Tracker

(Future Design), Low-Temp. Storage; HR-7

Solar Engine; LT ORCS, 2-Cover Pond,

Seasonal Aquifer and Low-Temp. Storage;

HR-7 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

PV Cogeneration; Two-Axis Concentrator

With Si Cells (Low Price), Multitank LowTemp. Storage; HR-7 . . . . . . . . . . . . . . . . . . . .

PV Cogeneration; Two-Axis Concentrator

With Si Cells (Low Price) Multitank LowTemp. Storage; HR-7. . . . . . . . . . . . . . . . . . . .

PV Cogeneration; Two-Axis Concentrator

PV Cogeneration; Two-Axis Concentrator

With GaAs Cells (LOW Price), Seasonal Low.

Temp. Storage; HR-8. . . . . . . . . . . . . . . . . . . . .

PV Cogeneration; Two-Axis Concentrator

With GaAs Cells (Low Price), Battery and

Multitank Low-Temp. Storage; HR-7 . . .

PV Cogeneration; One-Axis Tracker With Si

Cells ($15/W Cells), and Multitank LowTemp. Storage; HR-7 . . . . . . . . . ., . . . . . . . .

PV System; One-Axis Tracker With Si Cells

($1/W cells), Multitank Low-Temp. Storage;

PV Cogeneration; Two-Axis Concentrator .

With High Eff. Cells, Multitank Low-Temp.

Storage; HR-7. . . . . . . . . . . . . . . . . . . . . . . . . .

286

287

288

289

290

291

292

293

294

295

296

297

298

299/300

301

302

303

304

66.0

18.8

18.8

9.2

35.4

53.7

13.9

16.85/ 21.04

12.21/ 17.69

7.75/ 12,21

3.71/ 10.09 ●

9.01/ 12.32

7.81/ 10.71

45.74/ 57.69

12.74/ 19.29

9.01/ 16.32

5.73/ 11.34

2.75/ 9.6 8

6.86/ 11.40

5.62/ 9.78

35.95/ 53.51

1 44. / 173. 153 / 181.

73. / 84. 90./ 101.

65./ 73. 81./ 90.

57./ 63. 75./ 81.

78./ 90. 91./ 103.

76./ 92. 87./ 103.

108./ 125. 129./ 147

125./ 170.

84./ 98.

78./ 88

74./ 80.

83./ 99.

75./ 98.

115./ 141.

133./ 177.

125./ 139.

119./ 130.

120./ 127.

119./ 136.

86./

1 35. /

109.

161.

0.0 NA/ NA NA/ NA 57./ NA 79./ NA 79./ N A 125./ NA

35.7 8.20/ 11.67 5.94/ 10.71 80./ 94. 93./ 107. 84./ 103. 121./ 140.

28.1 17.73/ 22.87 13.91/ 21.23 105. / 121. 1 20./ 135. 108. / 130. 147, / 169.

100.0 17.85/ 21.51 13.98/ 19.85 220./ 260 . 220./ 260 . 177. / 242. 177. / 242.

46.4 6.41/ 8.8 7 4.89/ 8.2 2 77./ 90. 90./ 102. 82./ 99. 11 1./ 128.

54.4 6.61/ 8.96 5.04/ 8.2 9 82./ 96. 93./ 107 . 84./ 103. 11 1./ 130.

82.3

100.0

30.1

35.9

68.9

7.04/ 9.2 7

17.66/ 21.27

20.06/ 26.12

9.20/ 12.57

5.861 7.87

5.25/ 8.5 7

13.88/ 19.66

15.10/ 24.01

7.03/ 11.65

4.45/ 7.2 6

99./ 120.

218./ 258 .

115./ 135.

84./ 97.

84./ 100.

104./ 124.

218./ 258 .

131./ 151.

98./ 111 .

95./ 110.

88./ 118.

176./ 240.

114./ 144.

89./ 108.

84./ 106.

108./ 137.

176./ 240.

151./ 180.

123./ 142.

107./ 128.
Effective cost of solar Levelized monthly cost

Summary descrlption of system Table Percent energy (¢/kWh) of energy service

numbe r sola r N o 2 0 % Projection 1 projection 2 Projection 2 Projection 3

credits ITC No credits No credits 20% ITC 20% ITC

Systems compared to reference system—Continued

Solar Engine; LT ORCS, 2-Cover Pond,

Seasonal Aquifer and Low-Temp. Storage;

HR-7 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Conv. Engine Cogeneration; Diesel/ORCS

Engines, Absorption and Electric Chillers,

Low-Temp. Storage (HR-8) . . . . . . . . . . . . . . .

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engine (Low Eff.), Multitank LowTemp. Storage; HR-8 . . . . . . . . . . . . . . . . . . .

Solar Engine Cogenerat!in; TW O- AXIS Dish,

Stirling Engine (Low Eff.), Multitank LowTemp. Storage; HR-8 . . . . . . . . . . . . . . . . . . . .

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engine (Low Eff.), High-Temp. and

Multitank LowTemp. Storage; HR-8 . . .

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engine (High Eff.), Multitank LowTemp. Storage; HR-8 . . . . . . . . . . . . . . . . . . . .

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engine (High Eff.), Battery Storage,

High- and Low-Temp. Storage; HR.8. . . . . . .

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engine (Low Eff.), High-Temp. and

Multitank Low-Temp. Storage; HR-8 . . . . . . .

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engine (High Eff.), Battery, High-,

and Low-Temp. Storage; HR-8 . . . . . . . . . . . .

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engine (High Eff.), Battery Storage;

HR-8 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engine (High Eff.), Battery, High-,

and Low-Temp. Storage; HR-8 . . . . . . . . . . . .

100-Percent Solar Engine Cogeneration; TwoAxis Dish, Stirling Engine (High Eff.), Battery, High-, and Low-Temp. Storage; HR-8.

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engine (High Eff.), Battery, High-,

and Low Temp. Storage; HR-7. . . . . . . . . . . .

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engine (High Eff.), Battery, High-,

and Low-Temp. Storage; HR-7 . . . . . . . . . . . .

Conv. Engine Cogeneration; Stirling Engine

(Low Eff.), Absorption and Electric Chillers,

Low-Temp. Storage (HR-8) . . . . . . . . . . . . . . .

305

306

307

308

309

310

311

312

313

314

315

316

317

318

319

100.0

35.6

50.9

62.5

65.3

67.3

80.4

82.0

86.5

98.9

96.2

100.0

98.7

98.1

38.0

16.46/

9.52/

7.23/

9.21/

9.23/

6.95/

11.22/

12.11/

14.28/

16.75/

21.81

11.86

9.26

11.56

11.60

9.02

14.15

15.06

17.81

21.21

5.66/ 19.54

7.53/ 22.14

7.09/ 21.47

17.10/ 21.42

4.72/ 6.2 7

11 .39/ 19.64

8.13/ 11.27

5.96/ 8.7 2

7.39/ 10.78

7.35/ 10.80

5.43/ 8.3 7

8.59/ 13.03

9.41/ 13.90

10.90/ 16.37

12.33/ 19.33

11.83/ 17.91

12.93/ 20.18

12.73/ 19.61

12.79/ 19.58

4.35/ 6.1 2

205./ 264.

77. / 87.

77./ 88.

97./ 113 .

99./ 116 .

83./ 99.

128./ 154.

138. / 164.

163. / 197.

206./ 255 .

190./ 231.

217./ 267 .

210./ 257 .

209./ 255.

59.1 66.

205./ 264 .

95./ 104 .

90./ 101 .

107./ 123.

108./ 125.

92./ 108 .

133./ 159.

142./ 169.

167./ 200.

206./ 255 .

191./ 232.

217./ 267 .

210./ 257 .

209./ 256.

76./ 82.

149. / 240.

89./ 101.

83./ 98.

94./

95./

81./

110./ 149.

118./ 159.

135./ 187.

158./ 234.

151./ 215.

166. / 246.

163. / 237.

163. / 236,

74./ 82.

17.

19.

03.

149./ 240.

105./ 117.

95./ 110.

103./ 127.

103./ 128.

89./ 111.

115./ 154.

122./ 163.

138./ 190.

159./ 235.

152./ 216.

166./ 246.

763./ 238.

163./ 236.

90./ 97.
->.,

Reference system

Conv. All Electric System; Central ChilledWater System and Fan Coil Units With

Resistance Heaters (HR-2) . . . . . . . . . . .

Systems compared to reference system

Solar Hot Water; Flat-Plates (1977 Prices);

HR-2 . . ., . . . . . . . . . . . . . .

Solar Hot Water; Flat-Plates (Future Price);

HR-2 . . . . . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; HR -2 . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; HR-2 . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; HR-2 . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; HR-2 . . . . . . . . . . . . . . . . . . . .

100%. Solar Heating; Flat-Plates (1977 Prices),

Seas. Low-Temp. Storage; HR-2. . . . . . . . . . .

1000/. Solar Heating; Flat-Plates (Future

Price), Seas. Low-Temp. Storage; HR-2 . . . .

100% Solar Heating; Flat-Plates (1977 Prices),

Seas. Aquifer Storage; HR-2. . . . . . . . . . . . . .

1000/. Solar Heating; Flat-Plates (Future

Price), Seas. Aquifer Storage; HR-2. . . . . . . .

PV System, T

WO-AXIS Concentrator With Si

Cells (Med. Price), Multitank Low-Temp.

Storage; HR-2. . . . . . . . . . . . . . . . . . . . . . . . . .

PV Cogeneration; Two-Axis Concentrator

With Si Cells (Med. Price), Multitank LowTemp. Storage; HR-2. . . . . . . . . . . . . . . . . . . .

PV Cogeneration; Two-Axis Concentrator

With Si Cells, Multitank Low-Temp.

Storage; HR-6. . . . . . . . . . . . . . . . . . . . . . . . . .

PV Cogeneration; Two-Axis Concentrator

With GaAs Cells, Multitank Low- Temp.

Storage; HR-2 . . . . . . . . . . . . . . . . . . . . . . . .

PV Cogeneration; Two-Axis Concentrator

With GaAs Cells (Low Price), Multitank

Low-Temp. Storage; HR-2, ., . . . . . .

PV Cogeneration; T

WO-AXIS Concentrator

With GaAs Cells (LOW Price), Seasonal LowTemp. Storage; HR-2 . . . . . . . . . . . . . . . . . .

PV System; Two-AxIs Concentrator With

GaAs Cells (Low Price), Seasonal Multitank

Low-Temp. Storage; HR-2. . . . . . . . . . . . . .

PV Cogeneration; One-Axis Concentrator With

Si Cells ($15/W Cells), Multitank Low-Temp.

Storage; HR-2. . . . . . . . . . . . . . . . . . . . . . . . . .

PV Cogeneration; One-Axis Concentrator With

Si Cells ($15/W Cells), Multitank Low-Temp.

Storage; HR-2. . . . . . . . . . . . . . . . . . . . . . . . . .

PV Cogeneration; One-Axis Concentrator With

Si Cells ($1/W Cells), Multitank Low-Temp.

Storage; HR-2. ... . . . . . . . . . . . . . . . . . . . . .

320

321

322

323

324

325

326

327

328

329

330

331

332

333

334

335

336

337

338

339

340

0.0

12.5

12.5

19.5

19.5

26,3

26,3

61.1

61.1

61.1

61,1

42.3

43.0

46.4

42.6

43.9

73.3

74.1

28.4

40.7

31.9

NAI NA

5.07/ 8.41

3.17/ 6.09

6.18/ 8.98

3.90/ 6,18

7.66/ 10.43

4.83/ 6.96

7.73/ 10.20

5.72/ 7.75

6.76/ 8.78

4.39/ 5.88

6.90/ 9.03

4.23/ 5.80

4.86/ 6.52

6.60/ 8.64

4.27/ 5.78

4.53/ 6.08

5.52/ 7.40

9.80/ 13.17

13.53/ 17.10

5.30/ 7.3

2

NA/

3.76/

2.35/

4.57/

2.88/

5.65/

3.56/

5.46/

3.98/

4.94/

3.19/

5.20/

3.16/

3.66/

4.98/

3.26/

3.24/

3.87/

6.97/

10.1 9/

3.98/

NA

7.05

5.74

8.29

5.75

9.57

6.42

9.24

7.00

8.01

5.37

8.30

5.35

6.00

7.95

5.35

5.53

6.70

11.96

15.67

6.76

87./

89. /

85. /

94./

87./

1 04. /

91./

127. /

106./

11 7./

92./

1 09. /

90./

96./

1 07./

91./

96./

1 09. /

115./

1 54. /

94./

NA

96.

91.

104

94.

116,

100.

152.

127.

138.

107.

124.

102.

109.

122.

102.

115.

133.

132.

179.

105..

11 3./

13. /

09./

16. /

08./

123./

111./

1 37./

116./

127./

103./

125./

106./

11 1./

123./

106./

1 04. /

1 17. /

135./

170./

113./

NA

20.

15.

25

16.

136.

120,

163.

138.

148.

118.

140.

118,

124.

138.

118.

123.

140.

151.

195.

124.

113./ NA

110./ 119.

107./ 114.

111./ 123.

105./ 115.

114./ 132.

105./ 118.

114./ 153.

98./ 130.

108./ 140.

90./ 113.

1 13. / 135.

98./ 114.

101./ 120.

111./ 133.

99./ 114.

88./ 116.

96./ 132.

121./ 145.

147./ 185.

106./ 121.

223./ NA

206./ 215.

203./ 210

199./ 212.

194./ 203.

196./ 213.

186./ 199.

157./ 197.

142./ 173.

152./ 184.

134./ 156.

178./ 200.

163./ 179.

163./ 181.

176 / 197.

163./ 179.

120./ 149.

128./ 164.

200./ 224.

213./ 251.

181./ 196.

0

-.

v!●
1 I I Effective cost of solar Levelized monthly cost

of energy service

Summary description of system Tabl e Percent energy (¢/kWh)

numbe r sola r N o 2 0 %

credits ITC

Projection 1 Projection 2 Projection 2 Projection 3

No credits No credits 20% ITC 20% ITC

Systems compared to reference system—Continued

PV Cogeneration; One-Axis Concentrator With

Si Cells ($1/w Cells), Multitank Low-Temp.

Storage; HR-2. . . . . . . . . . . . . . . . . . . . . . . . . 341

PV Cogeneration; Two-Axis Concentrator

With High Eff. Cells, Multitank Low-Temp.

Storage; HR-2. . . . . . . . . . . . . . . . . . . . . . . . . . 342

PV Cogeneration; Two-Axis Concentrator

With High Eff. Cells, Seasonal Low-Temp.

Storage; HR-2. . . . . . . . . . . . . . . . . . . . . . . . . . 343

PV Cogeneration; Two-Axis Concentrator

With High Eff. Cells, Seasonal Multitank

Low-Temp. Storage; HR-2. . . . . . . . . . . . . . . . 344

46.1 6.51/ 8.4 3 4.98/ 7.7 8 108./ 123. 123. / 138. 111./ 133. 173./ 195.

49.1 4.431 5.9 2 3.36/ 5.4 6 95.1 107. 110./ 122. 101./ 118. 163./ 181.

85.7 4.90/ 6.4 9 3.49/ 5.8 9 106./ 129. 112./ 136. 92./ 127. 117./ 152.

98.1 3.35/ 4.4 5 2.44/ 4.0 7 87./ 105 . 91./ 110 . 76./ 103. 95./ 122.

87.4 7.93/ 9.7 1 6.20/ 8.9 7 153./ 180. 160./ 186. 134./ 175. 159./ 201.

90.7 8.35/ 10.12 6.59/ 9.3 7 165./ 192. 171./ 198. 144./ 186. 169./ 212.

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engine (Low Eff.), High-Temp. and

Multitank Low-Temp. Storage; HR-6 . . . . . . .

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engine (Low Eff.), High Temp. and

Multitank Low-Temp. Storage; HR-6 . . . . . . .

Reference system

Conv All Electric System, Resistance Heat,

Individual Window A/C, and Electric Water

Heaters (HR-4 )

Systems compared to reference system

PV System; Air-Cooled Si Arrays ($ 1/W), HR-4

PV System; Air-Cooled Si Arrays ($ 1/W), HR-4

PV System, Air-Cooled Si Arrays ($ 1/W), Battery Storage; HR-4

PV System, Air-Cooled Si Arrays ($0.50/W),

HR- 4

PV System, Air-Cooled Si Arrays ($0 501 W),

HR- 4

PV System: Air-Cooled Si Arrays ($0.50/W).

HR-4

PV System, Air-Cooled Si Arrays ($0 501 W),

Battery Storage, HR- 4

PV System; Air-Cooled Si Arrays ($050/W):

HR-4

PV System, Air-Cooled Thin-Film Arrays

($0.30/W), HR-4

PV System; Air-Cooled Thin-Film Arrays”

($0.30/W); HR-4 . . . . . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Thin-Film Arrays Vertical ($O.1O/W); HR-4. . . . . . . . . . . . . . . . . . .

345

346

347

348

349

350

351

352

353

354

355

356

357

358

0.0

9.2

NA/ NA NA/ NA 215./ NA

3.94/ 21.80

4.11/ 21.96

5.87/ 24.28

7.84/ 12.57

2.64/ 18.39

83./ NA

31./ 147 .

44./ 163 .

49./ 169.

05./ 115 .

20./ 131 .

NA

69.

84.

89.

37.

53.

109./ NA

137./ 162.

145./ 175.

149./ 180.

118./ 133.

131./ 148.

121./ 139.

162./ 205.

149./ 188

09./

53./

65./

69./

27./

42. /

18.94/

1 9.19/

21 .37/

10.66/

16.33/

10.79/

1 7.49/

12.64/

11.22/

11.01/

23.93

24.13

225./

230./

250.

23.5 260.

22.7

19.2

18.4

23.5

41.3

46.7

11.5

12.9

5.2

26.63 233./ 264.

13.78 206. / 221.

19.97

13.80

218./

206./

235.

7.93/ 12.58 224,

13.23/ 19.51

9.31/ 14.38

8.23/ 13.65

8.09/ 13.29

2.461 6.3 5

111./ 123.

176./ 202.

158./ 182.

97./ 104 .

98./ 106 ,

82./ 85.

132./ 144.

191./ 218.

175. / 199.

21.33 226./ 269.

15.80

14.93

219./

209./

258,

120./ 127. 220.

121 ./ 129.

1 07. / 110.

25.

26.

10.

114./

115./

106./

14.53 208./ 220.

3.441 6.77 207./ 211.
PV System; Air-Cooled Thin-Film Arrays Vertical ($O.1O/W); HR-4. . . . . . . . . . . . . . . . . . . .

PV System, Air-Cooled Thin-Film Arrays

($0.10/W) HR4

PV System; Air-Cooled Thin-Film Arrays

($0.10/W, HR-4

PV System, Air-Cooled Thin-Film Arrays

($0.10/W), Battery Storage: HR4

PV System, Air-Cooled Thin-Film Arrays

($0.10/w) HR-4

ALBUQUERQUE SHOPPING CENTER

Reference system

Conv. Gas Heat, Hot Water, and Central Electric A/C (SC-1). . . . . . . . . . . . . . . . . . . . . . .

Systems compared to reference system

Solar Hot Water; Flat-Plates (1977 Prices);

-- . 4

9

1 29

14.8

162

16.50 0

3.0

30

0.0

9.7

19.8

19.8

30.1

30.1

19.6

24.1

-848

30.1

30.1

15.2

3.95/ 753

6.96/ 9.56

6.92/ 9.38

7.391 983

6.93/ 9.30

2.83/ 7.05

5.10/ 8.77

5.08/ 8.60

5.46/ 9.01

5.08/ 8.51

83. /

89. /

91./

92./

92, /

8.5/

88./

86./

86.

95.

97.

99.

98.

108. / 110

112./ 118.

113./ 119.

114./ 121.

1 14. / 120.

107./ 110.

108./ 116.

109./ 117.

109./ 119.

109./ 118.

114./ NA

114./ 121

112./ 119

208./

202./

201./

1 99. /

199./

211.

210.

209.

209.

208.

359

360

361

362

363

364

. . 365

NA/ NA NA/ NA NA 114./ NA NA

8.99/ 22.44

5.53/ 18.20

6.64/ 21.44

4.08/ 17.59

95.

92.

115.1 122

113.I 120,

217./

216./

225.

223

SC-1 . . . . . . . . . . . . . . . . . . . . . . . . . ~ . . .

Solar Hot Water; Flat-Plates (Future price),

SC-1 . . . . . . . . . . . . . . . . . . 365/401

—.

Reference system

—.

Conv. Gas Heat, Hot Water, and Absorption

Chilling (SC-7’). . . . . . . 366

Systems Compared to reference system

Conv. Gas Heat, Hot Water, and Double- Effect Absorption Chilling (SC-7) . . . . . . . . . . . 367

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage, sC-7 ... . . . . . . . . . . . . . . . 368

Solar Heating; Flat-plates (Future price), Low.

Temp. Storage; SC-7 . . . . . . . . . . . . . . . . . . . . 368/405

100% Solar Heating and Cooling; Flat-Plates

(1977 prices), Seas. Low-Temp. Storage;

SC-7 . . . . . . . 369

Solar Heating; Flat-Plates (Future Prices), LowTemp. Storage; SC-7 . . . . . . . . . . . . . . . . . . . . 69/407

Solar Heating and Cooling; One-Axis Tracker

(1977 Design), Low-Temp. Storage; SC-7 . . . 370

Solar Heating and Cooling; One-Axis Tracker

(Future Design), Low-Temp. Storage; SC-7 . 371

Solar Heating and Cooling; One-Axis Tracker 372 (Future Design), Low-Temp. Storage; SC-7 .

Solar Heating and Cooling; One-Axis Tracker

(Future Design), Seasonal Low-Temp. Stor- 373 age; SC-7. . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Heating; One-Axis Tracker (Future

Design), Cheap Seasonal Storage; SC-7. . . . 374

Solar Engine Cogeneration; ORCS, One-Axis

Tracker (Future Design), Multitank HighTemp. Storage, Absorption Chillers; SC-7 . . 375

NA/ NA NAI NA

.581 4.46

10.53/ 16.90

5.70/ 10.32

9.67/ 15.87

6.05/ 10.32

9.88/ 15.99

3.33/ 6.26

-1.10/ -1.97

5.17/ 8.50

4.31/ 7.43

34.91/ 51.30

79. / NA 115./ NA 115./

1 04./

130./

NA 202./ NA

76./

1 19. /

96./

136./

108./

115./

85./

149./

82.

135.

109.

159.

125.

131.

96.

160.

105./

142./

120./

153./

125./

139./

106./

235./

112.

158,

132.

176.

142.

154.

117.

246.

111.

53.

186./

206. /

189./

204./

184. /

204./

175./

364./

193.

229.

205.

238.

207.

226.

188.

378,

.91/

13.81/

7.76/

13.20/

8.25/

12.97/

4.42/

-1 .44/

4.60

18.30

11.20

17.37

11.25

17.31

6.73

-2.12

112./ 129.

133./ 168.

113./ 137.

128./ 150.

101./ 114.

230./ 244.

108./ 127

104./ 121

216./ 262

6.72/ 9 16 100./ 113. 1 17./ 130. 179 I 197

8.02 94./ 107. 111./ 124. 174./ 191

44.88/ 55.56 193. / 223. 273. 262./ 308.
Effective cost of solar Levelized monthly cost

Summary description of system Table Percent energy (¢/kWh) of energy service

numbe r sola r No 2 0 % Project Ion 1 Projection 2 Projection 2 Projection 3

credits ITC No credits No credits 20% ITC 20% ITC

Systems compared to reference system—Continued

Solar Engine Cogeneration; ORCS, One-Axis

Tracker (Future Design), Multitank HighTemp. 011 Storage, Absorption Chillers;

SC-7 ., . . . . . . . . . . . . 376 36.5 19.97/ 24.85 15.35/ 22.88 189./ 222. 227./ 260. 196./ 247. 231./ 282.

●

Reference system

Conv. All-Electric Shopping Center (SC-2)

●

377 0.0 NA/ NA NA/ NA 90./ NA 120./ NA 120./ NA 239./ NA

Systems compared to reference system

Solar Hot Water: Flat-Plates (1977 Prices);

SC- 2

Solar Hot Water; Flat-Plates (Future Price); ”

SC-2 . .

Solar Heating; Flat-Plates (1977 Price), LowTemp. Storage: SC-2 . . . . . . . . . .

Solar Heating; Flat-Plates (Future Design),

Low-Temp. Storage, SC-2 ... . . . . . .

Solar Heating; Flat-Plates (1977 Price),

Seasonal Low-Temp. Storage: SC-2 . . . . .

Solar Heating; Flat-Plates (Future Price),

Seasonal Low-Temp. Storage, SC-2

PV System; Air-Cooled Si Arrays ($0 501 W);

SC-2 ., . . . . . . . .

PV System; Air-Cooled Si Arrays ($1/W); SC-2.

PV System; Air-Cooled Thin-Film Arrays

($0.10/W); SC-2 . . ...

PV Cogeneration; Two-Axis Concentrator

With High Eff. Cells, Multitank Low-Temp.

Storage; SC-2 . . . . . . . . . . . . . . . . . . .

PV Cogeneration; Two-AxIs Concentrator

With High Eff. Cells, Battery and Multitank

Low-Temp. Storage; SC-2 . . . . . . . . . . . .

378

378/416

379

379/418

380

8.5 2.78/ 6.6 4 2.05/ 6.3 3 89,/ 96.

88./ 94.

92,/ 100 .

89./ 95.

95./ 105 .

91./ 99.

160./ 187,

238./ 282.

113. / 128.

125./ 145.

127. / 147.

116. / 123.

11 5./ 121.

118. / 126.

1 15./ 122.

120./ 130.

116. / 124.

181./ 207

258./ 302 .

136. / 150.

141./ 161.

144. / 163.

1 15. / 122. 225./ 233.

8.5 1.71/ 5.33 1.26/ 5.1 4 1 14. / 120. 224./ 231.

12.7

12.7

3.59/ 6.5 8

2.20/ 4.8 7

2.65/ 6.1 8

1.62/ 4.6 2

116. / 125. 224.1 233.

1 14. / 121. 221./ 229.

18.1

18.1

60.4

60.4

4.41 / 7.06

3.12/ 5.4 9

7.76/ 9.9 8

14.27/ 17.96

3.14/ 6.5 2

2.19/ 5.0 9

5.72/ 9.1 1

10.52/ 16.36

116, / 128. 217./ 229.

112./ 123. 214./ 224.

156./ 197 239./ 27 9

214./ 283. 296./ 366.

380/422

381

3811423

382 42.1 4.86/ 6.6 2 3.57/ 6.0 8 125./ 146. 216./ 237.

383 86.8 3.96/ 5.1 0 3.02/ 4.7 0 125./ 154. 191./ 219.

384 80.6 4.36/ 5.5 8 3.33/ 5.1 4 127./ 156. 194./ 222.

FORT WORTH SHOPPING CENTER

Reference system

Conv. Gas Heat, Hot Water, and Central Electric A/C (SC-1). . . . . . . . . . . . . . . . . . . . . . . . . 385 0.0 NA/ NA NA/ NA 103./ NA 137./ NA 137./ NA 264./ NA
Systems compared to reference system

Solar Hot Water; Flat-plates (1977 Prices);

SC-I . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-plates (Future Price);

SC-1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Heating and Cooling; Absorption A/C,

One-Axis Tracker (Future Design LowTemp. Storage; SC-7 . . . . . . . . . . . . . . . . . . . .

Solar Heating and Cooling; Absorption A/C,

One-Axis Tracker (Future Design), LowTemp. Storage; SC-7 . . . . . . . . . . . . . . . . . . . .

Solar Heating and Cooling; Absorption A/C,

One-Axis Tracker (Future Design), LowTemp. Storage; SC-7 . . . . . . . . . . . . . . . . . . . .

Solar Heating and cooling; Absorption A/C,

One-Axis Tracker (Future Design), Seasonal

Low-Temp. Storage; SC -7 . . . . . . . . . . . . . . . .

Solar Heating and Cooling; Absorption A/C,

One-Axis Tracker (Future Design), Seasonal

Low-Temp. Storage; SC-7 . . . . . . . . . . . . . . .

Solar Heating and Cooling; Absorption A/C,

One-Axis Tracker (1977 Design), Seasonal

Low-Temp. Storage; SC-7 . . . . . . . . . . . . . . .

Solar Engine Cogeneration; ORCS and OneAxis Tracker (Future Design), 011 Backup,

Multitank High-Temp. 011 Storage; SC-7. . . . — ..— . .

Reference system

Conv. All-Electric Shopping Center (SC-2) . . . .

Systems compared to reference system

Solar Hot Water; Flat-Plates (1977 Prices);

SC-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-Plates (Future Price);

SC-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; SC-2 . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Price), LowTemp. Storage; SC-2 . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices),

Seasonal Low-Temp. Storage; SC-2 ... , . . .

Solar Heating; Flat-Plates (Future Price)

Seasonal Low-Temp. Storage; SC-2 . . . . .

PV System; Air-Cooled Si Arrays ($0.50/W);

SC-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Si Arrays ($ I/W); SC-2.

PV System; Air-Cooled Thin-Film Arrays

($0.10/W); Building Equipped SC-2 . . . . . . . .

138.I 148

137./ 146.

264./

262.I

273.

271.

386

386/401

387

388

389

390

391

391/407

392

2.5

2.5

2 29

18.4

18.7

30.6

30.6

30.6

-2.5

12.07/ 32.09

7.36/ 26.34

8.92/ 30.75

5.44/ 25.52

107./ 116/

105./ 114.

140./ 149

137./ 146

8.62/ 12.63

13.69/ 19.19

6.22/ 11.60

10.06/ 17.64

110./ 127

123./ 141.

1 33. / 150.

148./ 166

123./

136. /

145

161

202./

218./

225

243

166./ 194.

129./ 151.

143./ 168.

210./ 250 .

209./ 242.

192./ 220. 168./ 210.

130./ 163.

141./ 178.

191./ 253.

241./ 289.

26.52/ 34.87 19.54/ 31.89 249./ 291

10.54/ 14.68

13.08/ 17.68

7.48/ 13.37

9.46/ 16.13

147./ 170.

161./ 186.

205./

216./

238.

253

25.28/ 32.57 18.50/ 29.68 228./ 269. 266./

296./

327.

.*. *.*, ● ✌☛☛☛☛ ● ☛☛☛☛☛✏ ● ☛☛☛☛☛ 269./ 301 . 345. —-—

393

394

394/416

395

395/420

396

396/422

397

3971423

398

0.0 NA/ NA NA/ NA

2.76/ 9.06

1.68/ 7.44

3.371 8.26

2.06/ 6.29

3.62/ 7.96

2.35/ 6.05

7.35/ 11.90

13.52/ 21.20

4.60/ 8.08

111./ NA 146./ NA

148./ 156.

146./ 153.

141./ 150.

1 37. / 146.

144./ 155.

139./ 148.

211./ 239.

288./ 334.

165./ 181.

146./ NA 290./ N

A

3.73/ 9.48

2.27/ 7.70

4.571 8.77

2.80/ 6.60

4.99/ 8.55

3.27/ 6.44

9.98/ 13.02

18.33/ 23.26

6.25/ 8.79

7.3 1 13./ 122.

7.3

11.3

11,3

15.1

15.1

46.4

46.4

32.3

46./ 155. 286./ 295.

45./ 153. 284./ 293.

38./ 149. 264./ 275.

35./ 145. 261./ 271.

111./ 119.

110./

106./

120.

115.

113./ 124. 140./ 153. 263./ 276. I m~

136./ 147. 259./ 271.

z;

186./ 228 297./ 339.

b

243./ 315. 354./ 426.

3D

108./ 118.

211.

307.

183./

261./ I ~ 154./ 176 272./ 295 -.m

136. / 152,

——

— 1
Effective cost of solar Levelized monthly cost

Summary description of system Table Percent energy (¢/kWh) of energy service

numbe r solar No 200/0 Projection 1 Projection 2 Projection 2 Projection 3

credits ITC No credits No credits 20% ITC 20% ITC

OMAHA SHOPPING CENTER

Reference System

Conv. Gas Heat, Hot Water, and Central Electric A/C (SC-1). . . . . . . . . . . . . . . . . . . . . . . . . .

Systems compared to reference system

Solar Hot Water; Flat-Plates (1977 Prices);

SC-I . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-Plates (Future Price);

Se-l . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Reference system

Conv. Gas Heat, Gas Hot Water, and Absorption Chillers (SC-7). . . . . . . . . . . . . . . . . . . . .

Systems compared to reference system

Conv. Gas Heat, Hot Water, and Double- Ef.

feet Absorption Chilling (SC-7) . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices), LowTemp. Storage; SC-7 . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Price); SC-7

100-Percent Solar Heating; Flat-Plates (1977

Prices), Seasonal Low-Temp. Storage; SC-7

Solar Heating; Flat-Plates (Future Price),

Seasonal Low-Temp. Storage; SC-7 ., . . . . .

Solar Heating; One-Axis Tracker (1977

Designs), Low-Temp. Storage; SC-7 . . . . . . .

Solar Heating; One-Axis Tracker (Future

Design), Low-Temp. Storage; SC-7 . . . . . . . .

Solar Heating and Cooling; One-Axis Tracker

(Future Design) and Low-Temp. Storage;

SC-7 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Heating; One-Axis Tracker (Future

Design), Low-Temp. Storage; SC-7 . . . . . . . .

Solar Heating and Cooling; One-Axis Tracker

(Future Design), Seasonal Low-Temp.

Storage; SC-7 . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Engine Cogeneration; ORCS, One-Axis

Tracker (Future Design), High-Temp. Storage; SC-7. . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

399 0.0 NA/ NA NA/ NA 85./ NA 112./ NA 112./ NA 210./ N A

400 2.4 13.54/ 35.32 10.01/ 33.82 90. / 98. 116./ 124. 114./ 124. 211./ 221.

401 2.4 8.26/ 28.87 6.10/ 27.95 87./ 96. 114./ 122. 113.I 121. 209./ 218,

—..

NA/ NA

1.60/ 7.9 2

20.25/ 27.48

12.73/ 18.27

19.43/ 25.41

12.21/ 16.57

23.69/ 31.46

11.73/ 18.00

13.27/ 17.73

3.64/ 4.8 6

10.41/ 14.21

● *****, ,.,...

NA/ NA

1 .02/ 7.67

14,90/ 25.20

9.33/ 16.83

14.33/ 23.23

8.99/ 15.20

18.02/ 29,04

8.97/ 16.82

10,07/ 16.36

2.78/ 4.4 9

7.89/ 13.13

******, ● **** *

79./ NA

78./ 86.

402 0.0 108. / NA 108./ NA 189. / NA

403

404

405

406

407

408

409

7.6

16.8

16.8

27.8

27.8

15.3

11.3

104./

153./

131./

179./

144./

158./

121.1

112,

174,

147.

208.

165.

179.

134.

103. / 112,

137. / 167.

121 ./ 143.

154. / 197.

128. / 158.

143. / 172.

116. / 131.

181 ./

212. /

196. /

224./

1 99. /

218./

1 93. /

190.

242.

218.

267.

229.

248.

208.

31. / 152.

09./ 125 .

61. / 190.

26./ 148 .

136. / 156.

- 97./ 109.

410

411

26.3

92.8

129./ 149.

88./ 108 .

147./

90. /

167.

110.

132. / 161.

77./ 104.

203./

85./

232.

113,

412 27.8 118. / 136. 135./ 153. 123. / 148. 1 93. / 219.

413 -1.8 196./ 229. 239./ 272. 210./ 260. 250./ 300.

Reference system

Conv. All-Electric (SC-2) . . . . . . . . . . . . . . . . . . . 414 0.0 NA/ NA NA/ NA 96./ NA 126./ NA 126./ NA 247./ NA
Systems compared to reference system

Solar Hot Water; Flat-Plates (1977 Prices);

SC-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Hot Water; Flat-Plates (Future Price);

SC-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices) and

Low-Temp. Storage; SC-2 . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Prices) and

Low-Temp. Storage; SC-2 . . . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (1977 Prices) and

Low-Temp. Storage; SC-2 . . . . . . . . . . . . . .

Solar Heating; Flat-Plates (Future Prices) and

Low-Temp. Storage: SC-2 ,.

100-Percent Solar Heating; Flat-Plates “(1977

Prices) and Seasonal Low-Temp. Storage;

SC-2 . . . . . . . . . . . .

100-Percent Solar Heating; Flat-Plates (Future

Prices) and Seasonal Low-Temp. Storage;

SC-2 . . . . . . . . . . .

PV System; Air-Cooied SI Arrays ($1/W)’ SC-2.

PV System; Air-Cooled Si Arrays ($1/W), Battery Storage; SC-2

PV System; Air-Cooled Si Array ($0.50/W); ‘ “

SC-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

PV System; Air-Cooled Thin-Film Arrays

($0.30/W); SC-2 . . . . . . . .

PV System; Air-Cooled Thin-Film Arrays

($0.10/W); SC-2 . . . . . . . . . . . . . . . . ...

PV System; Air-Cooled Thin-Film Arrays

($0.10/W) Battery Storage; SC-2. ., . . . . . . .

PV Cogeneration; Two-Axis Concentrator

With High Eff. Cells, Battery and Multitank

Low-Temp. Storage, SC-2 . . . . . . . . . . . . . .

PV Cogeneration;

T WO -A XIS Concentrator

With High Eff. cells, Multitank Low-Temp.

Storage, SC-2 . . . . . . . . . . . . . . . . . . . . . . . . . .

ALBUQUERQUE COMMUNITY

Conventional systems

Conv. Heating and Cooling Systems in Each

Building: Mixture of Gas/Electric Hot

Water, Gas/Heat-pump/Resistance Heating.

and Electric Chilling

Conv. Heating and Cooling Systems in Each

Building, All Use Electric Hot Water,

Resistance Heating, Electric Cooling, and

Utility Electricity . . .

415

416

417

418

419

420

421

422

423

424

425

426

427

428

429

430

431

432

6,6

6.6

101

10.1

12,6

126

24.2

2 42

46.5

45.4

46.5

25.2

32.5

32.3

63.1

66.9

0.0

0.0

4.18/ 10.42

33961 46.86

5131 973

4,46/ 9.01

6.82/ 11.09

4.42/ 8.14

11.31/ 14.58

8.92/ 11.64

8.53/ 23.47

9.79/ 24.92

0.08/

3.53/

6.28/

6.47/

6.09/

5 12/

NA/

N A/

13.12

17.97

8.78

9.01

7.82

6.70

NA

NA

3,09/ 9.95

25.11/ 43.08

3.79/ 9.16

3.15/ 8.51

5.06/ 10.34

3.29/ 7.66

9.25/ 13.69

7.47/ 11.3

13.66/ 21.40

14.68/ 22.74

7.43/

9.97/

4.62/

4.77/

4.68/

3.89/

NA/

NA/

11.99

1646

8.07

8.29

7.23

6.18

NA

NA

97. /

1 35. /

1 00, /

98. /

1 05, /

99. /

1 33. /

122./

237. /

244./

160./

148./

116./

116./

127./

1 20. /

90./

129./

105,

152.

109.

108.

116

108.

149.

135.

283

290.

188.

170.

132.

132.

149.

141.

NA

NA

125./

163.I

27./

26.I

32./

26./

156./

1 45. /

255./

261./

178./

171./

1 37. /

138./

139. /

126./

174. /

133.

180.

136.

135,

142

135

172.

158.

301.

307.

206.

193.

153.

154.

161.

153,

NA

NA

123./ 132.

152./ 175.

124./ 135

123./ 134.

127./ 141.

123./ 134.

147./ 168.

138./ 155.

211./ 282.

215./ 288.

153./ 195.

153./ 186.

126./ 149.

127./ 149.

122./ 154.

116./ 147.

126./ NA

174/ NA

237./ 246.

265./ 289.

235./ 245.

233.I 244.

236./ 249.

231./ 242.

240./

232./

284./

287./

227./

249./

213./

213./

1 70. /

1 66. /

225./

357./

262.

249.

355.

360

269

281.

236.

236.

202.

196.

NA

NA
Effective cost of solar Levelized monthly cost

Summary description of system Tabl e Percent ,

energy (¢/kWh) of energy Service

numbe r sola r N o 2 0 % Projection 1 projection 2 Projection 2 Projection 3

credits ITC No credits No credits 20% ITC 20% ITC

Reference system

Conv. Heating and Cooling Systems in Each

Building; All Use Electric Hot Water and

Cooling; the High Rises and Shopping

Center Use Resistance Heating, Other

Buildings Use Heat Pumps . . . . . . . . . . .

Systems compared to reference system

Conv. Engine Cogeneration; Oil-Burning

Diesel/ORCS, Absorption and Electric

Chillers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Conv. Engine Cogeneration; Gas-Burning

Diesel/ORCS, Absorption and Electric

Chillers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Conv. Engine Cogeneration; Coal Steam Turbines and Absorption and Electric Chillers.

100-Percent Solar Heating; l-Cover Pond,

Seasonal Aquifer Storage, Electric Chillers,

and Utility Electricity. . . . . . . . . . . . . . . . . . . .

100-Percent Solar Heating; l-Cover Pond,

Seasonal Aquifer Storage, Electric Chillers,

and Utility Electricity. . . . . . . . . .

100-Percent Solar Heating; Flat-Plates (1977

Prices), Seasonal Low-Temp. Storage,

Absorption Chillers, and Utility Electricity .

100. Percent Solar Heating; Flat-Plates (Future

Price), Absorption Chillers, Low-Temp.

Storage, and Utility Electricity. . . . . . . . . . . .

Solar Engine Cogeneration; Steam Turbines,

Heliostats, High- and Low-Temp. Storage,

Absorption and Electric Chillers and Coal

Backup . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Engine Cogeneration; Heliostats, Steam

Turbines With Coal Superheat, High- and

Low-Temp. Storage, Absorption and Electric Chillers, and Coal Backup. . . . . . . . . . . .

Solar Engine Cogeneration; Two-Axis Dish,

High Eff. Stirling Engines, High- and LowTemp. Storage, Absorption and Electric

Chillers, and Oil Backup. . . . . . . . . . . . . . . . .

Solar Engine Cogeneration; Two-Axis Dish,

High Eff. Stirling Engines, High- and LowTemp. Storage, Absorption and Electric

Chillers, and Gas Backup. . . . . . . . . . . . . . . .

433

434

G434

435

436

437

438

439

440

441

442

G442

0.0

54.0

54.0

41.7

54.7

54.7

67.0

66.9

70.1

66.4

91.4

91.4

NA/ NA

5.33/ 8.0 8

5.33/ 8.0 8

9.18/ 13.85

6.67/ 9.8 6

5.52/ 8.2 8

7.82/ 11.90

5.71/ 8.9 0

7.91/ 11.56

7.75/ 11.37

6.05/ 8.7 1

6.05/ 8.7 1

NA/ NA

4.68/ 7.3 1

4.68/ 7.3 1

8.02/ 12.45

5.90/ 8.9 4

4.88/ 7.5 0

6.81/ 10.68

4.93/ 7.9 6

6.98/ 10.44

6.831 10.26

5.38/ 7.9 2

5.38/ 7.9 2

125./

1 22./

101 ./

125./

140./

127./

157./

128./

1 50. /

144./

146. /

143./

NA

152

131.

165.

175.

158.

213.

172.

203.

193.

164./ NA

135./ 166.

118./ 148.

136./ 175.

155./ 191.

143. / 173.

66./ 222 .

38./ 181 .

56./ 208 .

164./ NA

128./ 157.

111./ 139.

126./ 164.

147./ 181.

135./ 165.

153./ 205.

127./ 168.

143./ 192.

150./ 199. 137./ 184.

96. 149./ 198. 137. / 184.

92. 146. / 195. 133. / 180.

325./ N A

189./ 218.

126./ 155.

157./ 195.

210./ 244.

199./ 228.

191./ 244.

165./ 207.

158./ 208.

155./ 202.

148./ 195.

136./ 183.
Solar Engine Cogeneration; Two-Axis Dish,

Low Eff. Stirling Engines, High- and LowTemp. Storage, Absorption and Electric

Chillers, and 011 Backup. . . . . . . . . . . . . . . . .

Solar Engine Cogeneration; Two-Axis Dish,

Low Eff. Stirling Engines, High- and LowTemp. Storage, Absorption and Electric

Chillers, and Gas Backup. . . . . . . . . . . . . . . .

100-Percent Solar Engine; Low-Temp. ORCS

With River-Water Condenser, 2-Cover Pond,

Seasonal Aquifer Storage, and Absorption

Chillers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

100-Percent Solar Engine; Low-Temp. ORCS

With Cooling Tower, 2-Cover Pond,

Seasonal Aquifer Storage, and Absorption

Chillers . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

100-Percent Solar PV Cogeneration; Two-Axis

Concentrator With Si Cells (Med. Price),

Seasonal iron-REDOX Electrical and

Multitank Low-Temp. Storage, and Absorption Chillers (Minimum Collector Area) . . . .

100-Percent Solar PV Cogeneration; Two-Axis

Concentrator With Si Cells (Med. Price),

Seasonal iron-REDOX Electrical and

Multitank Low-Temp. Storage, and Absorption Chillers (Optimized Collector Area).

FORT WORTH COMMIUNITY

Conventional systems

Conv. Heating and Cooling Systems in Each

Building; Mixture of Gas/Electric Hot

Water, Gas/Heat-Pump/Resistance Heating,

and Electric Chilling . . . . . . . . .

Conv. Heating and Cooling Systems in Each

Building; All Use Electric Hot Water,

Resistance Heating, Electric Cooling, and

Utility Electricity . . . . . . . . . . . . . . . . . . . .

Reference system

Conv. Heating and Cooling Systems in Each

Building: All Use Electric Hot Water and

Electric Cooling; High Rises and Shopping

Center Use Resistance Heating, Other

Buildings Use Heat Pumps ., . . . . . . . . . .

Systems compared to reference system

Conv. Engine Cogeneration; 011-Burning

Diesel/ORCS, and Absorption and Electric

Chillers ., . . . . . . . . . . . . . . . . . . . . .

Conv Engine Cogeneratfin; Gas-Burning

Diesel/ORCS, and Absorption and Electric

Chillers . . . . . . . . . . . . . . . . . . . . . . . . . . . .

443

G443

444

445

446

447

450

451

G451

448

449

90.4

90.4

100.0

100.0

100.0

1000

0.0

0.0

0.0

53.1

53.1

6.63/ 9.36

6.63/ 9.36

8.85/ 12.33

11 .07/

9.34/

7.88/

NAI

NA/

NA/

5.28/

5.28/

15.28

13.15

11.20

NA

NA

NA

8.24

8.24

5.95/ 8.54

5.95/ 8.54

7.95/ 11.25

9.96/

8.38/

7.05/

NAI

NA/

N A/

4.61/

4.61/

13.95

12.00

10.19

NA

NA NA

7.43

7.43

1 57. /

152./

207./

252./

217./

188./

117./

145./

148./

132./

113./

207.

203.

278.

338.

295.

255,

NA

NA

NA

166.

147.

159./

156./

207./

252./

217./

188./

158./

193./

194./

145./

133./

210.

206.

278.

338

295.

255.

NA

NA

NA

179.

166.

147. / 195,

43. / 191.

89./ 256.

230./ 311

198./ 271.

171./ 235.

158./ NA

193./ NA

194./ NA

138./ 170.

125./ 157.

160. /

47. /

89. /

230. / .

98./

71. /

294./

392./

381./

200./

143./

207.

194.

256.

311.

271

235.

NA

NA

NA

232.

175.
Effective cost of solar Levelized monthly cost

Summary description of system Table Percent energy (¢/kWh) of energy service

numbe r solar N o 20% Projection 1 Projection 2 Projection 2 Pro]ection 3

credits ITC No credits No credits 20% ITC 20% ITC

Systems compared to reference system—Continued

Conv. Engine Cogeneration; Coal Steam Turbines, and Absorption and Electric Chillers

Solar Engine Cogeneration; Steam Turbines,

Heliostats, High- and Low-Temp. Storage,

Absorption and Electric Chillers, and Coal

Backup . . . . . . . . . . . . . . . . . .

Solar Engine Cogeneration; Steam Turbines

With Coal Superheat, Heliostats, High- and

Low-Temp. Absorption and ElectricChillers, and Coal Superheat . . . .

OMAHA COMMUNITY

Conventional systems

Conv. Heating and Cooling Systems in Each

Building; Mixture of Gas/Electric Hot

Water, GaslHeat-Pump/Resistance Heating,

and Electric Chilling

Conv. Heating and Cooling Systems” in Each

Building; All Use Electric Hot Water,

Resistance Heating, Electric Cooling, and

Utility Electricity . . . . . . . . . . . . . .

Reference system

Conv. Heating and Cooling System in Each

Building; All Use Electric Hot Water and

Electric Cooling; High Rises and Shopping

Center Use Resistance Heating, Other

Buildings Use Heat Pumps . . . . .

Systems compared to reference system

Conv. District Heating; Central Oil Heat and

Electric Chilling, and Utility Electrlcity

Conv. District Heating; Central Oil Heat and

Electric Chilling, and Utility Electricity

Conv. Engine Cogeneration, Oil-Burning

Diesel/ORCS, Absorption and Electric

Chiller s

Conv. Engine Cogeneration; Gas-Burning

Diesel/ORCS, Absorption and Electric

Chillers

Conv. Engine Cogeneration; Coal Steam Turbines, Absorption and Electric Chillers

100-Percent Solar Heating; l-Cover Pond,

Seasonal Aquifer Storage, Electric Chillers,

and Utility Electricity ...

100-Percent Solar Heating; Coal Steam Turbines, Absorption and Electric Chillers

452

453

454

455

456

457

458

G458

459

G459

460

461

461/437

37.6

65.8

62.5

0.0

0.0

0.0

34.9

34.9

558

558

455

60.1

601

1 0.37/

9.89/

9.62/

NA/

NA/

NA/

4,49/

4.49/

4.98/

4.98/

7.72/

7.29/

7 01/

15.92

14.46

14.16

NA

NA

NA

7.49

7.49

7 7 0

7 7 0

11 85

1063

1003

9.01/

8.73/

8.47/

NA/

NA/

NA/

3.87/

3.87/

4,34/

4.34/

6.71/

6.48/

6.28/

14.29

13.07

12.79

NA

NA

NA

6.73

6.73

6.93

6.93

10.63

9.66

9.16

141 /

187./

1 77. /

98. /

131 ./

1 30. /

127. /

11 6./

1 34. /

114 /

1 39. /

1 74. /

1 70./

186,

251.

238.

NA

NA

NA

152.

140,

170.

150.

183.

221.

212.

1 53. /

1 93./

184. /

1 33. /

1 74. /

168./

149./

140./

147./

1 30./

150./

188./

184./

198.

258.

245.

NA

NA

NA

174.

164.

183.

166,

194

236.

227.

142./ 185. 1 77./

177. / 238. 196. /

169./ 227

133./ NA

174./ NA

168./ NA

144./ 168.

134./ 158.

138./ 173

122./ 156.

139./ 181

177. / 222

174./ 215

190./

235./

351./

326./

237./

203./

197./

137./

173./

237./

234./

220.

257.

248.

NA

NA

NA

261.

226.

232.

171.

215

282.

275
Solar Engine Cogeneration, Heliostats, Steam

Turbines, High- and Low-Temp Storage,

Absorption and Electric Chillers, and Coal

Backu p

Solar Engine Cogenerat’ion; Heliostats, Steam

Turbines With Coal Superheat, High- and

Low-Temp. Storage, Absorption and Electric Chillers, and Coal Backu p

Solar Engine Cogeneration; Two-Ax Is Dish,

High Eff. Stirling Engine, High- and LowTemp Storage, Absorption and Electric

Chillers, and 011 Backup. ., . . . . . . . . . . .

Solar Engine Cogeneration; Two-Axis Dish,

High Eff. Stirling Engines, High- and LowTemp. Storage, Absorption and Electric

Chillers, and Gas Backup . . . . . . . . . . . . . . .

Solar Engine Cogeneration; Two-Axis Dish,

Low Eff. Stirling Engines, High- and LowTemp. Storage, Absorption and Electric

Chillers, Oil Backup. . . . . . . . . . . . . . . . . . .

Solar Engine Cogeneration; Two-Ax Is Dish,

Low Eff. Stirling Engines, High- and LowTemp. Storage, Absorption and Electric

Chillers, Gas Backup

100-Percent Heat Engine, LOW-Temp, ORCS

With River Water Condenser, 2-Cover Pond,

Seasona Aquifer Storage, and Absorptio n

Chillers . . . . . . . . . . .

100-Percent Solar Engine, Low-Temp. ORCS

With Cooling Tower, 2-Cover Pond,

Seasonal Aquifer Storage, Absorptio n

Chillers . . . . . . . . . . . . . . . . . . . . . . . .

100-Percent solar PV Cogeneration; Two-Axis

Concentrator With Si Cells (Med. Price),

Seasonal Iron-REDOX Electrical and

Multitank Low-Temp. Storage, Absorption

Chillers (Mlnimum Collector Area) . . . . . . . .

100-Percent Solar PV Cogeneration; TW O- AXIS

Concentrator With Si Cells (Med. Price),

Seasonal iron-REDOX Electrical and

Multitank, Low-Temp. Storage, Absorption

Chillers (Optlmlzed Collector Area). . . . . .

ALBUQUERQUE INDUSTRIAL

Reference system

Conv. Coal Boiler and Utility Electricity (lndustrial Owner )

Systems compared to reference system

Solar Process Heat (180° F), 2-Cover Pond,

Low-Temp Storage, Coal Backup Boiler,

and Utility Electricity (Industrial Owner)

462

463

464

G464

465

G465

466

467

468

469

470

471

677

651

875

875

858

858

100.0

100.0

1000

100.0

8.83/ 12.89

8.41/ 12.37

7.42/ 10.68

7.42/ 10.68

8.05/ 11.39

8.05/ 11.39

10.45/ 14.29

14.30/ 19.54

12.93/ 18.06

11.09/ 15.62

7.80/ 11.65

7.41/ 11.17

6.60/ 9.70

6.60/ 9.70

7.22/ 10.39

7.22/ 10.39

9.47/ 13.11

12.91/ 17.88

11.63/ 16.50

9.93/ 14.2 3

188./ 253.

177./ 238.

197.I 264.

191./ 258.

208.I 276.

202./ 269.

280./ 371.

371./ 495.

339./ 460.

296./ 40 3

195./ 260.

184./ 245.

200./ 268.

196./ 263.

212./ 280.

207./ 274.

280./ 371 .

371./ 495 .

339./ 460 .

296./ 403.

178./ 240.

169./ 227.

184./ 248.

179./ 243.

195./ 260.

190./ 254.

257./ 343.

339./ 456.

308./ 423.

268./ 370.

198./ 260.

191./ 248.

200./ 264.

183./ 247.

214./ 278.

195./ 259.

257./ 343.

339./ 456.

308./ 423.

268./ 370.

0.0 NA/ NA NA/ NA 1744./ NA 2332./ NA 2332./ NA 4352./ NA

17.9 11 06/ 5.22 9.93/ 4.6 7 2776./ 2131. 3266./ 2622. 3142./2561 4871./ 4290
Effective cost of solar Levelized monthly cost

Percent energy (¢/kWh) of energy service

solar No T

200/0 Project Ion 1 Project ion 2 Project ion 2 Project ion 3

credits ITC No credits No credits 20% ITC 20%IT C

Summary description of system Tabl e

numbe r

Systems compared to reference system—Continued

Solar Process Preheat (180° F max ), 2-Cover

Pond, Low-Temp Storage, Coal Backup

Boiler, and Utlllty Electrlclty (Industrial

Owner) 472

Solar Process Heat (180° F), 2-Cover Pond,

(Future Price). Low-Temp Storage, Coal

Backup Boiler, and Utility Electrlclty (ln -

dustrlal Owner). 471/494

Solar Process Preheat (180° F max.); 2-Cover

Pond, (Future Price), Low-Temp Storage,

Coal Backup Boiler, and Utlllty Electrlcity

(Industrial Owner ] 4721495

Solar Process Heat (180° F), Flat-Plates (1977

Prices), Low-Temp Storage, Coal Backup

Boiler. and Utllity Electrlclty (Industnal

(Owner) 473

Solar Process Heat (180 0 F); Flat~Plate’s

(Future Price), Low-Temp Storage. Coal

Backup . 4731497

Solar Process Heat (180” F), One-Axis Tracker

(1977 Design), High-Temp Storage, Coal

Backup Boiler, and Utility Electrlcity (lndustrial Owner ) 474

Solar Process Heat (350 0 F), One-Axis Tracker

(Future Design), High-Temp Storage, Coal

Backup Boiler, and Utility Electricity (lndustrial Owner ) 475

Solar PV Cogeneration. Two-Ax Is Concentrators With GaAs Cells (Med. Price), LowTemp. Storage, Coal Backup Boiler, and

Utility Electric Backup (Industrial Owner) 476

Solar PV Cogeneration; TW O- AXIS Concen -

trators With GaAs Cells (Low Price), LowTemp. Storage, Coal Backup Boiler, and

Utility Electric Backup (Industrial Owner) 477

35.2

17.9

35.2

35.6

35.6

26.9

25.3

0.0

17.9

5.63/ 2.6 6 5.06/ 2.3 8 2593./ 1949. 2991./ 2346. 2866./2285 4316./ 3735.

8.12/ 3.3 7 7.30/ 2.9 7 2451 ./ 1927. 2942./ 2417. 2852./2373. 4581. / 4103.

2269./ 1744.

5241 ./ 3441.

3862./ 2622.

5885./ 3940.

4.1 4/ 1.72

17.66/ 9.4 6

11.37/ 5.7 2

26.74/ 14.98

3.72/ 1,5 1

15.63/ 8.4 5

10.06/ 5.0 7

23.80/ 13.54

2666./ 2142,

5636./ 3836.

4257./ 3017.

6328./ 4382.

2576./2097. 4026. / 3547.

5190./3617, 6633./ 5060.

3969./2876. 5413./ 4319.

5842./4143. 7427. / 5728.

13.10/ 6.7 0 11.69/ 6.0 0 3517./ 2520. 3968. / 2971. 3748./2862. 5359. / 4473.

NAI NA

5.36/ 7.7 2

NA/ NA

4.90/ 7.1 6

1468. / NA

1871 ./ 2131.

2056./ N A

2362. / 2622.

2056. / NA 4076./ NA

231 1./2561. 4041. / 4290.

Reference system

Conv. Coal Boiler and Utility Electricity

(Municipal Utility Owner) . . . . . . . . . . . . . . . . M470 44.7

Systems compared to reference system

Solar Process Heat (180° F); 2-Cover Pond,

Low-Temp. Storage, Coal Backup Boiler,

10.51/ 5.5 9 9.34/ 5.0 2 4145. / 2790. 4499. / 3144. 4178./2986. 5417. / 4226.

and Utility Electricity (Municipal” Utility

Owner). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . M471 47.0 6.77/ 3.4 0 6.04/ 3.0 4 3181./ 2204. 3525./ 2548. 331 1./2443. 4501. / 3632,
Solar Process Preheat (180° F max.); 2-Cover,

Low-Temp. Storage, Coal Backup Boiler,

and Utlllty Electrlclty (Municipal Utlllty

Owner). . . . . M472

Solar Process Heat (180 0 F), 2-Cover Pond, ” “

(Future Price), LowTemp Storage, Coal

Backup Boiler, and Utility Electrlclty

(Municipal Utlllty Owner) . . . . . . M471/494

Solar Process Preheat (180° F max.); 2-Cover

Pond (Future Price), Low-Temp. Storage,

Coal Backup Boiler, and Utility Electriclty

(Municipal Utility owner) ., . . . . . . M472/495

Solar Process Heat (180° F); Flat-Plates (1977

Prices), Low-Temp. Storage, Coal Backup

Boiler, and Utility Electrlclty (Munlclpal

Utility Owner) . . . . . . . . . . . . . . . . . . . . . . . . . . M473

Solar Process Heat (180° F); Flat-Plates

(Future Price), Low-Temp. Storage, Coal

Backup Boiler, and Utillty Electrlclty

(Municipal UtilitV Owner) . . . . . . . . . . . . . . M473/497

Solar Process Heat (350 0 F); One-Axis Tracker

(Future Design), High-Temp. Storage, Coal

Backup Boiler, and Utlllty Electricity

(Municipal Utility Owner) . . . . . . . . . . . . . . .

Solar Process Heat (350”); One-Axis Tracker

(1977 Design), High-Temp. Storage, Coal

Backup Boiler, and Utility Electricity (industrial Owner). . . . . . . . . . . . . . . . . . . . . . . . .

Solar PV Cogeneration; Two-Axis Concentrators With GaAs Cells (Medium Price),

Low-Temp. Storage, Coal Backup Boiler,

and Utility Electric Backup (Municipal Utility Owner). . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar PV Cogeneration; Two-Axis Concentrators With GaAs Cells (Low Price), LowTemp. Storage, Coal Backup Boiler, and

Utility Electric Backup (Municipal Utility

Owner). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Reference system

Conv. Engine Cogeneration; Coal-Burning

Steam Turbine (Industrial Owner) . . . . . . . . .

Systems compared to reference system

Solar Engine Cogeneration; Heliostat, Steam

Turbines, High-and Low-Temp. Storage,

and Coal Backup (Industrial Owner) . . . . . . .

Reference system

Conv. Engine Cogeneration; Coal-Burning

Steam Turbine (Municipal Utility Owner)

Systems compared to reference system

Solar Engine Cogeneration; Heliostats, Steam

Turbines, High- and Low-Temp. Storage,

and Coal Backup (Municipal Utility Owner) .

M474

M475

M476

M477

—

35.2

17.9

35.2

35.6

3 5 6

26.9

25.3

44.7

47.0

2.73/ 393

3.98/ 5.8 7

2031 2.9 9

7 30/ 10.71

4.67/ 6.98

11 .77/ 16.65

5.87/ 8.47

4.57/ 6.5 9

3.00/ 4.35

2.50/ 3.6 5

3.65/ 5 4 6

1 .86/ 2.78

6.47/ 9.7 1

4.13/ 6.33

10.57/ 15.21

5.301 7.7 7

4.10/ 6.0 2

2.70/ 3 9 9

1689. / 1949.

1718.1 1927

1536./ 1744.

2693.1 3441.

2115.I 2622.

3132.I 3940.

2116. / 2520.

2233./ 2790

1812./ 2204

2086. / 2346.

2209 / 2417.

1934. / 2142

3088.1 3836.

2511 / 3017

3575. / 4382

2567. / 2971.

2587. / 3144.

2155. / 2548.

478 0.0 NA/ NA NA/ NA 1786. / NA 2269./ N A

479 47.4 1 1.09/ 5.40 9.89/ 4.8 1 4237. / 2748. 4491 ./ 3002.

2035 /2285 3485 / 3735

2172.12373 3902 / 4103

1897./2097 3347 I 3547

290613617 4349 / 5060

2393.12876. 3836.1 4319.

3376 /4143. 4961 I 5728

2477./2862. 4087 f 4473.

2456./2986. 3695. / 4226.

2068./2443. 3257. / 3632.

2269./ NA 3719. / NA

4177./2848. 4940. / 3610.

M478 0.0 NA/ NA NA/ NA 1315. / NA 1799. / NA 1799. / NA 3249, / NA

M479 47.4 4.93/ 7.1 9 4.44/ 6.6 0 2155. / 2748. 2409./ 3002. 2281./2848. 3043. / 3610.
Effective cost of solar Levelized monthly cost

Table Percent energy (¢/kWh) of energy service

Summary descrlption of system numbe r sola r N o 200/0 Project Ion 1 Projection 2 Projection 2 Pro]ectlon 3

credits ITC No credits No credits 20% ITC 20% ITC

Reference system

Conv. Oil Boiler and Utlllty Electricity (industrial Owner). . . . . . . . . . . . . . . . . . . . . ., 480

Systems compared to reference system

Solar Process Heat (180° F); 2-Cover Pond,

Low-Temp. Storage, Oil Backup Belier, and

Utility Electricity (Industrial Owner) . . . . . . . 481

Solar Process Preheat (180” F max.); 2-Cover

Pond Collector, Low-Temp. Storage, Oil

Backup Boiler, and Utility Electricity (industrial Owner). . . . . . . . . . . . . . . . . . . . . . . . . 482

Solar Process Heat (180° F); 2-Cover Pond

(Future Price), Low-Temp. Storage, Oil

Backup Boiler, and Utility Electricity (industrial Owner). . . . . . . . . . . . . . . . . . . . . . 481/507

Solar Process Preheat (180° F max.); 2-Cover

Pond (Future Price), Low-Temp. Storage, Oil

Backup Boiler, and Utility Electricity (In- .

dustrial Owner). . . . . . . . . . . . . . . . . . . . . . . . . 482/508

Solar Process Heat (180° F); Flat-Plates (1977

Prices), Low-Temp. Storage, Oil Backup

Boiler, and Utility Electricity (Industrial

Owner). . . . . . . . . . . . . . . . . . . . . . . . . . 483

Solar Process Heat (180° F); Flat-Plates

(Future Price), Low-Temp. Storage, Oil

Backup Boiler, and Utility Electricity (industrial Owner). . . . . . . . . . . . . . . . . . . . . 483/510

Solar Process Heat (350° F); One-Axis Tracker

(1977 Design), High-Temp. Storage, Oil

Backup Boiler, and Utility Electricity (lndustrlal Owner). . . . . . . . . . . . . . . . . .

Solar Process Heat (350° F); One-Axis Tracker

(Future Design), High-Temp. Storage, Oil

Backup Boiler, and Utility Electricity (industrial Owner). . . . . . .

Solar PV Cogeneration: TW O- AXIS Concen -

trators With GaAs Cells (Med. Price), LowTemp. Storage, 011 Backup Boiler, and Utlllty Electrlc Backup (Industrial Owner). ., .,

Solar PV Cogeneration; Two-Axis Concentrators With GaAs Ceils (Low Price), LowTemp. Storage, 011 Backup Boiler, and Utlllty Electric Backup (Industrial Owner), ...

484

485

486

487

0.0

17.9

35.2

17.9

35.2

35.6

35.6

26.9

25.3

44.7

47.0

NA/ NA

11 .04/ 6.80

5.62/ 3.47

8.10/ 4.95

4.13/ 2.52

17.66/ 10.26

11 .36/ 6.51

26.74/ 16.05

13.1 0/ 7.83

10.51 / 6.23

6.77/ 4.01

NA/ NA

9.91/ 6.2 5

5.05/ 3.1 8

7.28/ 4.5 5

3.71/ 2.3 2

15.63/ 9.2 6

10.05/ 5.8 7

23.80/ 14.60

11 .69/ 7.13

9.34/ 5.6 6

6.04/ 3.6 5

2228./ N A

3018./ 2550.

2605. / 2137.

2693./ 2345.

2281./ 1933.

5249. / 3625.

3868./ 2805.

601 1./ 4241.

3663./ 2842.

4234. / 3055.

3288./ 2487.

3028./ N A

3662. / 3195.

3100./ 2632.

3338./ 2990.

2775./ 2427.

5740. / 4116.

4359./ 3296.

6577. / 4807.

4244, / 3422.

4704. / 3525.

3752./ 2950.

3028./ NA 6594./ N A

3538./3133. 6383./ 5979,

2975./2571. 5127./ 4722.

3248./2946. 6093. / 5791.

2685./2383, 4837./ 4535.

5294./3897. 7429. / 6032.

4072./3154, 6207./ 5289.

6091./4568. 8577. / 7054.

4024./3314. 6574. / 5864.

4383./3367. 6460. / 5444.

3538./2845. 5597./ 4904.

●
Reference system

Conv. Oil Boiler and Utlllty Electrlclty

(Munlclpal Utlllty Owner) M480

Systems compared to reference system

Solar Process Heat (180” F), 2-Cover Pond,

Low-Temp. Storage, Oil Backup Boiler, and

Utlllty Electriclty (Municipal Utlllty Owner) M481

Solar Process Preheat (180° F max ), 2-Cover

Pond, Low-Temp. Storage, Oil Backup

Boiler, and Utlllty Electriclty (Munlclpal

Utility Owner) . M482

Solar Process Heat (180° F); 2-Cover Pond

(Future Price), Low-Temp Storage, 011 Backup

Boiler, and Utlllty Electrlclty (Munlclpal Utlllty

Owner) M481/50

7

Solar Process Preheat (180° F max.); 2-Cover

Pond (Future Price), LowTemp. Storage, Oil

Backup Boiler, and Utlllty Electrlclty

(Munlclpal Utility Owner) . . . . . . . . M482/508

Solar Process Heat (180° F): Flat-Plates (1977

Prices), LowTemp. Storage, Oil Backup

Boiler, and Utlllty Electrlclty (Munlclpal Utlllty

Owner). . . . . . . . . . . . . . . . . . . . . . M483

Solar Process Heat (180” F); Flat-Plates

(Future Price), Low-Temp. Storage, Oil Backup

Boiler, and Utlllty Electricity (Munlclpal Utility

Owner) M483/51O

Solar Process Heat (350° F); One-Axis Tracker

(1977 Design), High-Temp. Storage, 011

Backup Boiler, and Utlllty Electnclty

(Municipal Utility Owner) . . . . . . . . . . . . . . . . M484

Solar Process Heat (350° F); One-Axis Tracker

(Future Design), High-Temp. Storage, Oil

Backup Boiler, and Utility Electric Backup

(Munlclpal Utility Owner) . . . . . . . . . . . . . . . . . . M485

Solar PV Cogeneration; T

WO-AXIS Concen-

trators With GaAs Cells (Med. Price), LowTemp. Storage, Oil Backup Boiler, and Utility

Electric Backup (Municipal Utility Owner) ., M486

Solar PV Cogeneration; Two-Axis Concentrators With GaAs Cells (Low Price), LowTemp. Storage, Oil Backup Boiler, and Utility

Electrlc Backup (Municipal Utllity Owner) M487

00

179

3 52

1 79

35.2

35.6

35.6

26.9

25.3

44.7

47.0

NA/ NA

5.36/ 717

2 73/ 365

3.97/ 532

2.02/ 2.71

7.30/ 10.44

4.66/ 6.70

11.77/ 16.29

5.87/ 8.09

4.57/ 6.38

3.00/ 4.15

NAI NA

4.90/ 661

2.49/ 337

3.64/ 491

1.85/ 2.50

6.47/ 9.44

4.13/ 6.05

10.57/ 14.85

5.30/ 7.39

4.10/ 5.81

2.70/ 3.79

2187 I NA

2350. / 2550,

1937 / 2137

2197 I 2345

1785 / 1933.

2937. / 3625.

2358./ 2805.

3493./ 4241.

2497./ 2842.

2558./ 3055.

2154./ 2487.

2988 I NA

2995 / 3195

2432. / 2632.

2842. / 2990

2279./ 2427.

3428./ 4116.

2849./ 3296.

4060./ 4807.

3078./ 3422.

3028./ 3525.

2617./ 2950.

2988 I NA 6553 / NA

2944 /3133 5789 I 5979

2381 /2571 4533 I 4722

2805./2946 5650 / 5791

2242./2383. 4394./ 4535.

3245./3897. 5380./ 6032.

2731./3154. 4867./ 5289.

3861 ./4568. 6347./ 7054.

2988./3314. 5538./ 5864.

2897./3367. 4973./ 5444.

2530./2845. 4588./ 4904.

Conventional oil systems

Conv. Engine Cogeneration; Industry Using

Oil-Burning Diesel (Industrial Owner) . . . . . . 488 0.0 NAI NA NA/ NA 2319. / NA 2981./ N

A 2981, / NA 6036. / NA

Conv. Engine Cogeneration; Oil-Burning

Diesel (Municipal Utility Owner) . . . . . . . . . . M488 0.0 NA/ NA NA/ NA 2082./ N

A 2744./ N

A 2744./ NA 5799. / N

A

—— I
Effective cost of solar Levelized monthly cost

Summary description of system Table Percent energy (¢/kWh) of energy service

numbe r sola r N o 200/0 Projection 1 Projection 2 Projection 2 Projection 3

credits ITC No credits No credits 20% ITC 20%IT C

,

Reference system

Conv. Engine Cogeneration; Oil-Burning Stirling Engine (Industrial Owner) . . . . . . . . . . . . 489 0.0 NA/ NA NA/ NA 2254./ N A 2890./ N A 2890./ NA 5822./ N A

Systems compared to reference system

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engines, High- and Low-Temp.

Storage, and Oil Backup (Industrial Owner). 490 52.4 14.17/ 8.2 2 12.63/ 7.4 6 4680./ 3278. 4983./ 3580. 4618./3400. 6012./ 4795.

Reference system .

Conv. Engine Cogeneration; Oil-Burning Stirling (Municipal Utility Owner). . . . . . . . . . . . . M489 0.0 NA/ NA NA/ NA 2135./ N A 2770./ N A 2770./ NA 5702./ N A

Systems compared to reference system

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engines, High- and Low-Temp.

Storage, and Oil Backup (Municipal Utility

Owner). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . M490 52.4 6.24/ 8.73 5.61/ 7.97 2691./ 3278. 2994./ 3580. 2844./3400. 4238./ 4795.

Reference system

Conv. Gas Boiler and Utility Electricity (industrial Owner). . . . . . . . . . . . . . . . . . . . . . . . . G480

Systems compared to reference system

Solar Process Heat (180° F); 2-Cover Pond,

Low-Temp. Storage, Gas Backup Boiler,

and Utility Electricity (Industrial Owner) . . . G481

Solar Process Preheat (180° F max.); 2-Cover

Pond, Low-Temp. Storage, Gas Backup

Boiler, and Utility Electricity (Industrial

Owner). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . G482

Solar Process Heat (180° F); 2-Cover Pond

(Future Price), Low-Temp. Storage, Gas

Backup Boiler, and Utility Electricity (industrial Owner). . . . . . . . . . . . . . . . . . . . . . G481/507

Solar Process Preheat (180° F max.); 2-Cover

Pond (Future Price), Low-Temp. Storage,

Gas Backup Boiler, and Utility Electricity

(Industrial Owner) . . . . . . . . . . . . . . . . . . . . G482/508

Solar Process Heat (180° F); Flat-Plates (1977

Prices), Low-Temp. Storage, Gas Backup

Boiler, and Utility Electricity (Industrial

Owner). ., . . . . . . . . . . . . . . . . . . . . . . . . . . . . . G483

Solar Process Heat (180° F); Flat-Plates

(Future Price), Low-Temp. Storage, Gas

Backup Boiler, and Utility Electricity (lndustriai Owner). ... , . . . . . . . . . . . . . . . . . . . . G483/510

0.0

17.9

35.2

17.9

35.2

35.6

35.6

NA/ NA

1 1.04/ 6.80

5.62/ 3.47

8.10/ 4.95

4.13/ 2.52

17.66/ 10.26

11.36/ 6.51

NA/ NA

9.91/ 6.2 5

5.05/ 3.1 8

7.28/ 4.5 5

3.71/ 2.3 2

15.63/ 9.2 6

10.05/ 5.8 7

1342./ N A

2379./ 1911,

2203./ 1735.

2054./ 1706.

1879./ 1531.

4853./ 3229.

3472./ 2408.

2279./ N A

3121./ 2653.

2759./ 2291.

2797./ 2449.

2435./ 2087.

5404./ 3780.

4024./ 2960.

2279./ NA 3898.1 N A

2997./2592. 4437./ 4033.

2635./2230. 3903./ 3498.

2707./2405. 4147./ 3845.

2345./2042. 3613./ 3311.

4958./3561. 6222./ 4825.

3736./2819. 5000./ 4082.
26.9 26.74/ 16.05 23.80/ 14.60 5494.1 3724. 6140./ 4370. 5654./4131 7005./ 5482.

25.3 13.10/ 7.8

3 11.69/ 7.1

3 3125./ 2303. 3788./ 2967. 3568.12858. 4935.1 4225.

Solar Process Heat (350° F); One-Axis Tracker

(1977 Design), High-Temp. Storage, Gas

Backup Boiler, and Utlllty Electrlclty (ln- .

dustrial Owner). ... . . . . . . . . . . . . G484

Solar Process Heat (350” F); One-Axis Tracker

(Future Design), High-Temp. Storage, Gas

Backup Boiler, and Utlllty Electricity (lndustrlal Owner). . . . . . . . . . . . . . . . . . . . . ... G485

Solar PV Cogeneratlon; Two-AxIs Concentrators With GaAs Cells (Med. Price), LowTemp. Storage, Gas Backup Boiler, and

Utlllty Electrlc Backup (Industrial Owner) . . G486 44.7 10.51/ 6.23 9.34/ 5.6

6 3755.1 2576. 4298. / 3119 3977./ 2961. 4999. / 3983

Solar PV Cogeneratlon; Two-Ax Is Concentrators With GaAs Cells (Low Price), LowTemp. Storage, Gas Backup Boiler, and

Utlllty Electric Backup (Industrial Owner) ., G487 47.0 6.77/ 4.0

1 6.04/ 3.65 2791.1 1989 3330, / 2529 31 17./2424. 4081. / 3388.

Reference system

Conv. Gas Boiler and Utility Electr!clty

(Munlcipal Utility Owner) ., . . . . . . . MG480

Systems compared to reference system

Solar Process Heat (180° F); 2-Cover Pond,

Low-Temp. Storage, Gas Backup Boiler,

and Utillty Electrlclty (Munlclpal Utility

Owner). . . . . . . . . . . . . . . . . . . . . MG481

Solar Process “Preheat (180° F max.); 2-Cover

Pond, LowTemp. Storage, Gas Backup

Boiler, and Uttltty Electrlclty (Munlclpal

Utlllty Owner) ., . . . . . . . . . . . . . . . . . . . . MG482

Solar Process Heat (180° F); 2-Cover Pond

(Future Price), Low-Temp.Storage, Gas

Backup Boiler, and Utility Electricity

(Munlclpal Utility Owner) . . . . . . . . . . .MG481/507

Solar Process Preheat (180° F max.); 2-Cover

Pond (Future Price, Low-Temp. Storage,

Gas Backup Boiler, and Utlllty Electricity

(Municipal Utillty Owner) . . . . . . . . . . . . . .MG482/508

Solar Process Heat (180° F); Flat-Plates (1977

Prices), Low-Temp. Storage, Gas Backup

Boiler, and Utility Electricity (Municipal

Utility Owner) . . . . . . MG483

Solar Process Heat (180° F); Flat-Plates

(Future Price), Low-Temp. Storage, Gas

Backup Boiler, and Utility Electrlclty

(Municipal Utility Owner) . . . . . . . . . . . . . . .MG483/510

Solar Process Heat (350 0 F); One-Axis Tracker

(1977 Design), High-Temp. Storage, Gas

Backup Boiler, and Utility Electricity

(Municipal Utility Owner) . . . . . . . . . . . . . . . . MG484

Solar Process Heat (350° F); One-Axis Tracker

(Future Design), High-Temp. Storage, Gas

Backup, Boiler, and Utility Electricity

(Municipal utility Owner) . . . . . . . . . . . . . . . . MG485

0.0 NA/ NA

17.9

35.2

17.9

35.2

35.6

35.6

26.9

253

5.36/

2.73/

3.97/

2.02/

7.30/

4.66/

11 .77/

5.87/

7.17

3.65

5.32

2.71

10.44

6.70

16.29

8.09

NAI NA 1302. / NA 2238. / NA 2238./ NA 3858. / N

A

4.90/

2.49/

3.64/

1.85/

6.47/

4.1 3/

1 0.57/

5.30/

6.61

3.37

4.91

2.50

9.44

6.05

14.85

7.39

1711./ 1911.

1535./ 1735.

1558. / 1706.

1383./ 1531.

2540. / 3229.

1962. / 2408.

2977. / 3724.

1959, / 2303.

2453./ 2653.

2091./ 2291.

2301./ 2449.

1939. / 2087.

3092./ 3780.

2514. / 2960.

3622./ 4370.

2622. / 2967.

2403./2592. 3843. / 4033.

2040 /2230. 3309,/ 3498.

2264./2405. 3704./ 3845.

1902./2042. 3170. / 3311.

2909./3561 4173./ 4825.

2396./2819. 3660. / 4082.

3423./4131 4775. / 5482

2532./2858. 3899. / 4225.

co●
Effective cost of solar Levelized monthly cost

Summary descriptIin of system Table Percent energy (¢/kWh) of energy service

numbe r sola r No 2 0 % Projection 1 Project Ion 2 Project Ion 2 Pro]ection 3

credit S ITC No credits No credits 20% ITC 20%IT C

Systems compared to reference system—Continued

Solar PV Cogeneration; Two-Axis Concentrators With GaAs Cells (Med. Price), LowTemp. Storage, Gas Backup Boiler, and

Utility Electric Backup (Municipal Utility

Owner). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . MG486 44.7 4.57/ 6.3 8

Solar PV Cogeneration; Two-Axis Concentrators With GaAs Cells (Low Price), LowTemp. Storage, Gas Backup Boiler, and

Utility Electric Backup (Municipal Utility

Owner). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . MG487 47.0 3.00/ 4.1 5

— .

Conventional gas systems

Conv. Engine Cogeneration; Gas-Burning

Diesel (Industrial Owner) . . . . . . . . . . . . . . . . G488

Conv. Engine Cogeneration; Gas-Burning

Diesel (Municipal Utility Owner) . . . . . . . . . . MG488

. .

Reference syste m

Conv. Engine Cogeneration; Gas-Burning Stlr -

Iing Engine (Industrial Owner) . . . . . . . . . . . . G48 9

Systems compared to reference syste m

Solar Engine Cogeneration; Two-Axis Dish ,

Stirling Engines, High- and Low-Temp .

Storage, and Gas Backup (Industrial Owner). . . .

Reference system

Conv. Engine Cogeneration; Oil-Burning Stirling Engine (Municipal Utility Owner) . . . . . . MG489

Systems compared to reference system

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engines, High- and Low-Temp.

Storage, and Oil Backup (Municipal Utility

Owner). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . MG490

0.0 NA/ NA

0.0 NAI NA

0 0 NA/ NA

4.1 0/ 5.81

2.70/ 3.7 9

NA/ NA

NA/ NA

NA/ NA

52.4 8.22 12.63/ 7 4 6

—

0.0 NA/ NA NA/ NA

52.4 6.24/ 8.73 5.61/ 7.97

2079./ 2576. 2622./ 3119. 2490./2961. 3513. / 3983.

1656. / 1989. 2196./ 2529. 210912424 3073.I 3388.

—

1275. / NA 2097./

1037. / NA 1859. /

1252. / NA 2041 ./

4204./ 2801 4579. /

NA 2097. / NA 2857./ NA

NA 1859. / NA 2619. / NA

—

NA 2041. / NA 2770 / NA

3176. 4214./2997 4561. / 3344,

1133./ N A 1922./ N A 1922./ NA 2651./ N A

2215./ 2801. 2590./ 3176. 2441./2997. 2787./ 3344.

OMAHA INDUSTRIAL

Reference system

Conv. Coal Boiler and Utility Electricity (industrial Owner). . . . . . . . . . . . . . . . . . . . . . . . . 491 0.0 NA/ NA NAI NA 1813. / NA 2429. / NA 2429./ NA 4563./ N A
Systems compared to reference system

Solar Process Heat (180° F) 2-Cover Pond

Low-Temp Storage, Coal Backup Boiler,

and Utlllty Electrlclty (Industrial Owner)

Solar Process preheat (180 : F max ) 2-Cover

Pond, Low-Temp Storage, Coal Backup

Boiler, and Utlllty Electrlclty (Industrial

Owner )

Solar Process Heat (180° F). 2-Cover Pond

(Future Price), Low-Temp Storage Coal

Backup Boiler. and Utlllty Electricity (industrial Owner).

Solar process Preheat (180° F max.); 2-Cover

Pond (Future Price), Low-Temp. Storage,

Coal Backup Boiler, and Utility Electricity

(Industrial Owner) ., ... , . . . . . . . . . . . . . . .

Solar Process Heat (180° F); Flat-Plates (1977

Prices), Low-Temp. Storage, Coal Backup

Boiler, and Utility Electricity (Industrial

Owner). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Process Heat (1800 F); Flat-Plates

(Future Price), Low-Temp. Storage, Coal

Backup Boiler, and Utility Electrlclty (industrial Owner). . . . . . . . . . . . . . . . . . . . . .

Solar Process Heat (3500 F); One-Axis Tracker

(1977 Design), High-Temp, Storage, Coal

Backup Boiler, and Utillty Electrlclty (industrial Owner) ... ... . . . . .

Solar Process Heat (350° F): One-Axis Tracker

(Future Design), High-Temp. Storage, Coal

Backup Boiler, and Utlllty Electricity (industrial Owner), . . . . . . . . . . . . . . . . . . . . . . .

PV Cogeneration System; Two-Axis Concentrators With GaAs Cells (Med. Price), LowTemp. Storage, Coal Backup Boiler, and

Utility Electrlc Backup (Industrial owner) . .

PV Cogeneratlon; Two-Axis Concentrators

With GaAs CeIls (Low price), Low-Temp.

Storage Coal Backup Boiler, and Utility

Electric Backup (Industrial Owner) . . . . . . .

Reference system

Conv. Coal Boiler and Utility Electricity

(Municipal Utility Owner) . . . . . . . . . . . . . . . .

Systems compared to reference system

Solar Process Heat (180° F); 2-Cover Pond,

Low-Temp. Storage, Coal Backup Boiler,

and Utility Electricity (Municipal Utility

Owner). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Process Preheat (180 0 F max.); 2-Cover

Pond Collector, Low-Temp. Storage, Coal

Backup Boiler, and Utility Electricity

(Municipal Utility owner) . . . . . . . . . . . . . . . .

492

493

494

495

496

497

498

499

500

501

M491

M492

M493

168

2 5 3

168

2 5 3

24.3

24.3

24.5

25.3

49.3

51.9

0.0

16,8

25.3

18.27/ 9 7 3

12.13/ 646

13.36/ 6.6 3

8.87/ 4.40

40.57/ 22.49

26.07/ 13.88

49.12/ 28.51

23.64/ 13.11

17.80/ 10.06

11.43/ 6.2 9

16 41/ 88 1

10 90/ 58 5

12.02/ 5.9 7

7 98/ 39 6

35.90/ 20.20

23.06/ 12.40

43,74/ 25.86

21.09/ 11.85

15.83/ 9.0 9

10.19/ 5.6 8

N A /

8.89/

5.90/

3530 I 2644

3440. / 2554.

3020. / 2323

2930. / 2233.

7636./ 4926.

5462./ 3635.

8963. / 5854.

5231. / 3589.

6608./ 4254.

4802./ 3159.

4054 / 3168

3918 / 3032.

3545. / 2847.

3409. / 2711.

8120. / 5411

5946./ 4119.

9446./ 6337.

5710./ 4068.

6938./ 4584.

51 14./ 3471.

NA NA/ NA 1538. / NA 2153./ N A

2.39 8.13/ 11.47 2281. / 2644. 2806./ 3168.

8.22 5.40/ 7.6 2 2191 / 2554. 2670 / 3032

3861 /3073

3725 /2937

3406./2779

3270 /2643.

7420./5066

5496./3898.

8634./5938.

5312./3872.

6340./4290.

471 7./3276.

2153./ NA

5722 / 4935

5449. / 4661.

5267. / 4640

4993. / 4366.

9159. / 6806

7235./ 5637

7036./ 5596.

7497, / 5448

5792./ 4350.

4287. / NA

2727 /3073 4588. / 4935.

2591 ./2937 4314./ 4661.
Effective cost of solar Levelized monthly cost

Summary description of system Table Percent ,

energy (¢/kWh) of energy service

number solar No 200/0 Projection 1 Projection 2 Projection 2 Projection 3

credits ITC No credits No credits 20%ITC 20% ITC

Systems compared to reference system—Continued

Solar Process Heat (1800 F); 2-Cover Pond

(Future Price), Low-Temp. Storage, Coal

Backup Boiler, and Utility Electricity

(Municipal Utility Owner) . . . . . . . . . . . . . . . .

Solar Process Preheat (180° F max.); 2-Cover

Pond (Future Price), Low-Temp. Storage,

Coal Backup Boiler, and Utility Electricity

(Municipal Utility Owner) . . . . . . . . . . . . . . . .

Solar Process Heat (180° F); Flat-Plates (1977

Prices), Low-Temp. Storage, Coal Backup

Boiler, and Utility Electricity (Municipal

Utility Owner) . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Process Heat (180° F); Flat-Plates

(Future Price), Low-Temp. Storage, Coal

Backup Boiler, and Utility Electricity

(Municipal Utility Owner) . . . . . . . . . . . . . . . .

Solar Process Heat (350° F); One-Axis Tracker

(1977 Design), High-Temp. Storage, Coal

Backup Boiler, and Utility Electricity

(Municipal Utility Owner) . . . . . . . . . . . . . . . .

Solar Process Heat (350° F); One-Axis Tracker

(Future Design), High-Temp. Storage, Coal

Backup Boiler, and Utility Electricity

(Municipal Utility Owner) . . . . . . . . . . . . . . . .

PV Cogeneration; Two-Axis Concentrators

With GaAs Cells (Med. Price), Low-Temp.

Storage, Coal Backup Boiler, and Utility

Electric Backup (Municipal Utility Owner) . .

PV Cogeneration; Two-Axis Concentrators

With GaAs Cells (Low Price), Low-Temp.

Storage, Coal Backup Boiler, and Utility

Electric Backup (Municipal Utility Owner) . .

M494

M495

M496

M497

M498

M499

M500

M501

16.8

25.3

24.3

24.3

24.5

25.3

49.3

51.9

6.571 9.2 9

4.37/ 6.1 7

16.77/ 24.33

10.70/ 15.72

21.71/ 30.34

10.57/ 14.88

7.75/ 10.96

5.06/ 7.1 5

6.02/ 8.6 3

4.00/ 5.7 3

14.86/ 22.04

9.47/ 14.24

19.50/ 27.69

9.53/ 13.62

6.95/ 10.00

4.56/ 6.5 4

2041./ 2323.

1951. / 2233.

3794./ 4926

2884./ 3635.

4553./ 5854.

2918./ 3589.

3278./ 4254.

2491./ 3159.

2566./ 2847. 2509./2779. 4370./ 4640.

2430./ 2711. 2373./2643. 4096./ 4366.

4278./ 5411. 3991./5066. 5731./ 6806

3368. / 4119.

5036./ 6337.

3397./ 4068.

3608./ 4584.

2803./ 3471.

3183./3898. 4923./ 5637.

4703./5938. 6441 ./ 7675.

3234./3872. 4958.1 5596.

3363./4290. 4521./ 5448.

2641 ./3276. 3715./ 4350.

Reference system

Conv. Engine Cogeneration; Coal-Burning

Steam Turbine (Industrial Owner) . . . . . . . . . 502 0.0 NA\ NA NA/ NA 1786. / NA 2269. / NA 2269./ NA 3719. / NA

Systems compared to reference system

Solar Engine Cogeneration; Heliostats, Steam

Turbines, High- and Low-Temp. Storage,

and Coal Backup (Industrial Owner) . . . . . . . 503 4 4 9 18.79/ 10.03 16.76/ 9.0 3 6015./ 3845. 6281 / 4111 5779./3864 6578. / 4662.

Reference system

Conv. Engine Cogeneration; Coal-Burning

Steam Turbine (Municipal Utility Owner) . . . M502 0.0 NA/ NA NA/ NA 1315. / NA 1799. / NA 1799. / NA 3249. / NA
Systems compared to reference system

Solar Engine Cogeneration; Heliostats, Steam

Turbines, High- and Low-Temp. Storage,

and Coal Backup (Municipal Utility Owner).

—

4 4 9

0 0

168

25.3

16.8

25.3

2 4 3

2 4 3

24.5

25.3

49.3

51.9

8.39/ 119 3 7.56/ 10.93 2970 I 3845 3236 / 4111 3030 /3864 3829./ 4662

. . — — .— -. —

M503

—

504

505

506

507

508

509

510

511

512

513

514

— —

—

Reference system

Conv. Oil Boiler and Utility Electricity (industrial Owner). . . . . . . . . . . . . . . . . . . . . . . . . NA/ NA NAI NA 2088. / NA 2840. / NA 2840. / NA 6167./ NA

Systems compared to reference system

Solar Process Heat (180° F); 2-Cover Pond,

Low-Temp. Storage, Oil Backup Boiler, and

Utility Electricity (Industrial Owner) . . . . . . .

Solar Process Preheat (180° F max.); 2-Cover

Pond, Low-Temp. Storage, Oil Backup

Boiler, and Utility Electricity (Industrial

Owner). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Process Heat (180° F); 2-Cover Pond

(Future Price), Low-Temp. Storage, Oil

Backup Boiler, and Utility Electricity (industrial Owner). . . . . . . . . . . . . . . . . . . . . . . . .

Solar Process Preheat (180° F max.); 2-Cover

Pond (Future Price), Low-Temp. Storage, Oil

Backup Boiler, and Utility Electricity (industrial Owner). . . . . . . . . . . . . . . . . . . . . . . . .

Solar Process Heat (180° F); Flat-Plates (1977

Prices), Low-Temp. Storage, Oil Backup

Boiler, and Utility Electricity (Industrial

Owner). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Process Heat (180° F); Flat-Plates

(Future Price), Low-Temp. Storage, Oil

Backup Boiler, and Utility Electricity (industrial Owner). . . . . . . . . . . . . . . . . . . . . .

Solar Process Heat (350° F); One-Axis Tracker

(1977 Design), High-Temp. Storage, Oil

Backup Boiler, and Utility Electricity (industrial Owner). . . . . . . . . . . . . . . . . . . . . . . . .

Solar Process l-teat (350 0 F); One-Axis Tracker

(Future Design), High-Temp. Storage, Oil

Backup Boiler, and Utility Electricity (industrial Owner). . . . . . . . . . . . . . . . . . . . . . . . .

PV Cogeneration; Two-Axis Concentrators

With GaAs Cells (Med. Price), Low-Temp.

Storage, oil Backup Boiler, and Utility Electric Backup (Industrial Owner). . . . . . . . . . . .

PV Cogeneration; Two-Axis Concentrators

With GaAs Cells (Low Price), Low-Temp.

Storage, Oil Backup Boiler, and Utility Electric Backup (Industrial Owner). . . . . . . . . . . .

— —. —

18.27/ 114 2 16.41/ 10.50 3634. / 2924. 4260.I 3549. 4067./3454. 6810 I 6197

3458./ 2748.

3125./ 2602.

4020. / 3309

3750. / 3228.

3827./3214 6274. / 5662.

3611 /3160 6354. / 5903

1 2.13/ 7.58

13.36/ 8.3 2

10.90/ 6.9 8

12.02/ 7.66

8.87/ 5,5 3 7.98/ 5.09 2949./ 2427. 3510.I 2988. 3371 ./2920. 5819./ 5367

7531 ./5355 ‘***’I 783 8 40.56/ 23.66

26 08/ 15.05

35.89/ 21.36

23.07/ 13.57

7662. / 5130. 8231./ 5699.

5493./ 3841 6063. / 4410. 5612./4188. 8094./ 6671

8744./6225. ● ***” I 8702,

5412./4148. 7860./ 6597.

6357./4484 8114 / 6241

4752 /3487 6453./ 5188.

49.11/

23 63/

9.67

4.23

43.73/ 27.02

21.07/ 12.97

15,82/ 96 6

8987./ 6056, 9556. / 6624.

5247. / 3782. 5809./ 4344.

17 79/ 10.63

11 .42/ 6.84

6556. / 4379. 6955./ 4778

10,18/ 6.2 3 4765. / 3298 5149./ 3682

.—
Summary description of system

Effective cost of solar Levelized monthly cost

Tabl e Percent energy (¢/kWh) of energy service

numbe r sola r No 20°% Projection 1 projection 2 Projection 2 Projection 3

credits ITC No credits No credits 20%IT C 20%IT C

Reference system

Conv. Boiler and Utility Electricity (Municipal

Utility Owner) . . . . . . . . . . . . . . . . . . . . . . . . . .

Systems compared to reference system

Solar Process Heat (180° F); 2-Cover Pond,

Low-Temp. Storage, Oil Backup Boiler, and

Utlllty Electricity (Munlclpal Utlllty Owner)

Solar Process Preheat (180” F max.); 2-Cover

Pond, Low-Temp. Storage, 011 Backu p

Boiler, and Utillty Electrlc~ty (Municipal

Utlllty Owner )

M504

M505

M506

M507

M508

M509

M51O

M511

M512

M513

M514

0.0

1 6 8

25.3

16.8

25.3

2 4 3

24.3

2 4 5

2 5 3

4 9 3

51.9

0.0

NA/ NA NA/ NA 2047.I NA 2799./ NA 2799./ NA 6127 / NA

8 89/ 1181 8.13/ 10.89 2621 I 2924

2445 I 2748.

2381./ 2602.

2205./ 2427.

4057. / 5130.

3148. / 3841.

4814. / 6056.

3172. / 3782.

3463.1 4379.

2691 / 3298.

3246. / 3549

3006./ 3309

3007/ 3228.

2767I 298 8

4626. / 5699.

3167 /3454 5910I 6197

2927 /3214 5375./ 5662

2950./3160. 5692/ 5903

2710 /2920. 5157. / 5367

4340 /5355 6822/ 7838

5.90/ 78 4

6.57/ 8.7 1

5.40/ 72 3

6.02/ 8.0 5

Solar Process Heat (180° F); 2-Cover Pond

(Future Price), Low-Temp. Storage, 011

Backup Boiler, and Utlllty Electrlclty

(Municipal Utlllty Owner )

Solar Process Preheat (180° F max.); 2-Cover

Pond (Future Price), Low-Temp. Storage, 01

Backup Boiler, and Utlllty Electrlclty

(Muntclpal Utiltty Owner) . . . . . .

Solar Process Heat (180” F); Flat-Plates (1977

Prices), Low-Temp. Storage, 011 Backup

Boiler, and Utillty Electricity (Munlclpal

Utlllty Owner) . ... ... . . . .

4.37/ 5 7 9 4 00/ 5.35

16 77/ 2393 14.86/ 21.63

Solar Process Heat (180” F); Flat-Plates

(Future Price), Low-Temp. Storage, Oil

Backup Boiler, and Utll!ty Electnclty

(Munlclpal Utlllty Owner) . . . . . . . . .

Solar Process Heat (350° F); One-Axis Tracker

(1977 Design), High-Temp. Storage, Oil

Backup Boiler, and Utility Electricity

(Munlclpal Utility Owner) . . . . . . . . . . . . .

Solar Process Heat (350° F); One-Axis Tracker

(Future Design), High-Temp. Storage, 011

Backup Boiler, and Utility Electnclty

(Municipal Utility Owner) . . . . . . . .

PV Cogeneratlon; TW O- AXIS Concentrators

With GaAs Cells (Med. Price), Low-Temp.

Storage, OIl Backup Boiler, and Utility Electric Backup (Munlclpal Utility Owner).

PV Cogeneratlon; Two-AxIs Concentrators

With GaAs Cells (Low Price), Low-Temp.

Storage, 011 Backup Boiler, and Utiltty Electrlc Backup (Municipal Utillty Owner). . . . . .

Conventional oil systems

Conv. Engine Cogeneratlon; Oil-Bur’ning

Diesel Engine (Industrial Owner). . . . . . . . . .

10.70/ 1533 9 47/ 13.84 3718. / 4410.

5382. / 6624

3733/ 434 4

3862. / 4778

3075./ 3682.

3533./4188. 6016 / 6671

21 70/ 29.94 19 50/ 27.29 5050 /6225 7527/ 8702

10.57/ 1449

7 75/ 1076

9 52/ 1323

6.95/ 9.8 0

3571 /4148 6019 / 6597

3617./4484. 5374. / 6241.

2912./3487. 4613./ 5188.

. —

2644. / NA 5284. / NA

5.06/ 6.9 6

NA/ NA

4.55/ 6.3 5

515 NA/ NA 2072./ N A 2644. / NA
Conv Engine Cogeneration; Otl-Burning

Diesel Engine (Munlc!pal Utlllty Owner). . . .

— .

Reference system

Conv Engine Cogeneratlon; Oil-Burning StIrIlng (Industrial Owner}, .

SYSWTemS compared to reference system

Solar Engine Cogeneratlon. Two-Axis Dish,

Stirling Engines, High and Low-Temp

Storage. and 011 Backup (Industrial Owner).

Reference system

Conv. Engine Cogeneratlon, 011-Burning StlrIlng (Munlclpal Utlllty Owner) .

Systems compared to reference system

Solar Engine Cogeneratlon; Two-Axis Dish,

Stlrl{ng Engines, High- and Low-Temp.

Storage, and 0il Backup (Municipal Utility

Owner). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

— — — —— . —— —

Reference system

Conv Gas Boiler and Utility Electricity (lndustrlal Owner). . . . . . . . . . . . . . . . . . . . . . .

Systems compared to reference system

Solar Process Heat (180° F); 2-Cover Pond,

Low-Temp. Storage, Gas Backup Boiler,

and Utlllty Electrlclty (Industrial Owner)

Solar Process Preheat (180° F max.): 2-Cover

Pond, Low-Temp. Storage, Gas Backup

Boiler, and Utlllty Electrlclty (Industrial

Owner). ... , ... , ., . . . . . . . . . . . . . . . . . . .

Solar Process Heat (180° F); 2-Cover Pond

(Future Price), Low-Temp. Storage, Gas

Backup Boiler, and Util!ty Electricity (lndustrlal Owner) .

Solar Process Preheat (180° F max.): 2-Cover

Pond (Future Price), Low-Temp Storage,

Gas Backup Boiler, and Utlllty Electricity

(Industnal Owner)

Solar Process Heat (180 0 F), Flat-Plates (1977

Prices). Low-Temp Storage, Gas Backu p

Boiler, and Utlllty Electrlclty (Industrial

Owner) ., . . . . . .

Solar Process t-teat (180° F); Flat-Plates

(Future Price), Low-Temp. Storage, Gas

Backup Boiler, and Utlllty Electrlclty (lndustrlal Owver) . . . . .

Solar Process Heat (350° F); One-Axis Tracker

(1977 Deslgn), High-Temp, Storage, Gas

Backup Boiler, and Utlllty Electricity (lndustnal owner). . . . . . . . . . . . . . . .

0 0

.

0 0

465

0 0

4 6 5

—

00

168

253

1 6 8

2 5 3

2 4 3

2 4 3

2 4 5

NA/ NA

—

NA/ NA/ 1834./ NA 2406./ NA

— —

2406./ NA 5046./ NA

.

M515

—

516

517

M516

M517

G504

G505

G506

G507

G508

G509

G51O

G511

NAI NA NA/ NA 2017 / NA 2566 / NA 2566. / NA 5100 / NA

26331 1554 23 45/ 1412 6821 / 4565 71 15, / 4859

—

6512 {4562 7867 / 5917

—

NA/ NA/ NA/ NA/ 1898./ NA 2447./ NA 2447 / NA 4980./ NA

3914/ 4859 3667./4562 5022 / 5917

. — — —

NA/ NA NA/

16.41/

10 90/

NA

0 5 0

696

1331 ./ NA 2210. / NA 2210 / NA 3864 / NA

78.27/ 1142 3075./ 2365 3794./’ 3084. 3601 /2989 5108. / 4496

12.13/ 75 8

13 36/ 8.32

2999./ 2289. 3637. / 2927 344412832, 4877 / 4264

1 2.02/ 7 6 6 2566. / 2044. 3285. / 2763. 3146./2694. 4653 / 4201
Effective cost of solar Levelized monthly cost

Summary description of system Tabl e Percent energy (¢/kWh) of energy service

numbe r sola r N o 2 0 % Projection 1 Project Ion 2 Projection 2 Project ion 3

credits ITC No credits No credits 20% ITC 20 IT C

i

Systems compared to reference system—Con

Solar Process Heat (350° F); One-Axis Tracker

(Future Design), High-Temp. Storage, Gas

Backup Boiler, and Utlllty Electricity (lndusrial Owner). . . . . . . . . . . . . . . . . . . . . .

PV Cogeneratlon; Two-Ax Is Concentrators

With GaAs Cells (Med. Price), Low-Temp.

Storage, Gas Backup Boiler, and Utility

Electrtc Backup (Industrial Owner) . . . . . . . .

PV Cogeneratlon; TW O- AXIS Concentrators

With GaAs Cells (Low Price), Low-Temp.

Storage, Gas Backup Boiler, and Utility

Electric Backup (Industrial Owner) . . . . .

u e d

G512

G513

G514

MG504

25.3 21 07/ 12.97 4788./ 3323 5427./ 3961. 5029./3766. 6461 / 5198.

49.3

51.9

— . .

0.0

16.8

23 63/ 1423

17.79/ 106 3

11 42/ 6.84

15.821 966 6176./ 3999 6639. / 4461 6040 /4167. 6957 I 5084.

1o.18/ 6 2 3 4368 / 2901. 4818 / 3352 4421/3156 5245. / 3979

Reference system

Conv. Gas Boiler and Utility Electricity

(Municipal Utility Owner) . . . . . . . . . . . . . . . . NA/ NA NA/ NA 1291./ N A 2169./ N A 2169. / NA 3824. / NA

Systems compared to reference system

Solar Process Heat (180° F); 2-Cover Pond,

Low-Temp. Storage, Gas Backup Boiler,

and Utility Electricity (Municipal Utility

Owner). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Process Preheat (180° F max.); 2-Cover

Pond, Low-Temp. Storage, Gas Backup

Boiler, and Utility Electricity (Municipal

Utility Owner) . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Process Heat (180° F); 2-Cover Pond

(Future Price), Low-Temp. Storage, Gas

Backup Boiler, and Utility Electricity

(Municipal Utility Owner) . . . . . . . . . . . . . . . .

Solar Process Preheat (180° F max.); 2-Cover

Pond (Future Price), Low-Temp. Storage,

Gas Backup Boiler, and Utility Electricity

(Municipal Utility Owner) . . . . . . . . . . . . . . . .

Solar Process Heat (180° F); Fiat-Plates (1977

Prices), Low-Temp. Storage, Gas Backup

Boiler, and Utility Electricity (Municipal

Utility Owner) . . . . . . . . . . . . . . . . . . . . . . . . . .

Solar Process Heat (180° F); Flat-Plates

(Future Price), Low-Temp. Storage, Gas

Backup Boiler, and Utility Electricity

(Municipal Utility Owner) . . . . . . . . . . . . . . . .

Solar Process Heat (350° F); One-Axis Tracker

(1977 Design), High-Temp. Storage, Gas

Backup Boiler, and Utility Electricity

(Municipal Utility Owner) . . . . . . . . . . . . . . . .

8.89/11.8 1

5.90/ 7.8 4

6.57/ 8.7 1

4.37/ 5.7 9

16.77/ 23.93

10.70/ 15.33

21.70/ 29.94

8.13/ 10.89

5.40/ 7.2 3

6.02/ 8.0 5

4.00/ 5.35

14.86/ 21.63

9.47/ 13.84

19.50/ 27.29

2062./ 2365.

1986. / 2289.

1822. / 2044.

1746. / 1968.

3586./ 4659.

2677./ 3370.

4345./ 5586.

2781./ 3084.

2624./ 2927.

2541./ 2763.

2384.1 2606.

4234./ 5307.

3325,/ 4018.

4991. / 6233.

2702./2989. 4209./ 4496.

2545./2832. 3977. / 4264.

2484./2694. 3991./ 4201.

2327./2537. 3760./ 3970.

3947./4962. 5389./ 6404.

3141./3796. 4582./ 5237.

4659./5834. 6099./ 7274.

MG505

MG506

MG507

MG508

MG509

MG51O

MG511

5.3

6.8

25.3

24.3

24.3

24.5
Solar Process Heat (350° F); One-Axis Tracker

(Future Design), High-Temp. Storage, Gas

Backup Boiler, and Utility Electricity

(Municipal Utility Owner) . . . . . . . . . . . . . . . . MG512 25.3

PV Cogeneration; Two-Axis Concentrators

With GaAs Cells (Med. Price), Low-Temp.

Storage, Gas Backup Boiler, and Utility

Electric Backup (Municipal Utility Owner) . . MG513 4 9 3

PV Cogeneration; Two-Axis Concentrators

With GaAs Cells (Low Price), Low-Temp.

Storage, Gas Backup Boiler, and Utility

Electric Backup (Municipal Utility Owner) . . MG514 51.9

——— .

Conventional gas systems

Conv. Engine Cogeneration; Gas-Burning

Diesel (Industrial Owner) ., . . . . . . . . . . . . . G515 0.0

Conv. Engine Cogeneration; Gas-Burning

Diesel (Municipal Utility Owner) . . . . . . . . . . MG515 0.0

10.57/ 14.49

7.75/ 10.76

5.06/ 6.9 6

N A I

NA/

— — .

Reference system

Conv. Engine Cogeneration; Gas-Burning Stirling (Industrial Owner). . . . . . . . . . . . . . . . . . . G516 0.0 NA/

Systems compared to reference system

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engines, High- and Low-Temp.

Storage, and Gas Backup (Industrial Owner). . . . G517 46.5 26.33/

NA

NA

—

NA

15,54

9.52/ 13.23

6.95/ 98 0

4.55/ 6.3 5

.

NA/ NA

NA/ NA

2712 I 3323.

3083 I 3999.

2294. / 2901.

— —

1180. / NA

942. / NA

NAI NA 1161. / NA

23.45/ 14.12 6363./ 4107.

3351 ./ 3961

3545. / 4461.

2744./ 3352.

.

1 901. /

1663. /

1853. /

6733.1

NA

NA

— —

NA

4477.

. .— — —

Reference system

Conv. Heat Engine Cogeneration; Gas- Burning Stirling (Municipal Utility Owner) . . . . . MG516

Systems compared to reference system

Solar Engine Cogeneration; Two-Axis Dish,

Stirling Engines, High- and Low-Temp.

Storage, and Gas Backup (Municipal

Owner). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . MG517

0.0 NA/ NA NA/ NA 1041./ N A 1734. / NA

46.5 11 59/ 1611 10.41 / 14.69 3162. / 4107. 3532./ 4477.

3188./3766. 4620 / 5198

3300 /4167. 4217 / 5084.

2581 ./31 56. 3404. / 3979

— . — —

1901 ./ NA 2568. /

1663. / NA 2330. /

—

1853. / NA 2492. /

NA

NA

NA

6131 ./4181 6473. / 4523.

—

1734. / NA 2373. / NA

3285./4181. 3628.1 4523

●
CATALOG OF ENERGY SYSTEMS

Footnotes for catalog tables

 a 1 Bbl. crude Oil is equivalent to 4.83 mmBtu after 17% loss due to refining,

transportation, etc. Combined electrical generation, transmission, and distribution

efficiency is 29 percent.

b The energy Cost escalation assumptions are described in detail in chapter II,

volume II. In alI cases, 5.5 percent inflation is assumed.

C The other costs assume that the energy equipment is owned by the building

owners (see page 97). The equipment in the conventional communities is also owned

by the owners of each of the buildings, while in the other communities, it is owned by

a municipal utility. In all cases, the parenthesized costs assume ownership by a n

investor-owned utility using normalized accounting.

d “1985 Startup” is the same as “1976 Startup” except that fuel costs have

escalated for 9 years. For ease of comparison with “1976 Startup, ” 5.5 percent infiation between 1976 and 1985 has been removed.

e These levelized prices are computed from the price paid for energy in the reference nonsolar system.

147
Table IV-1 .-Albuquerque: Conventional System–Single Family House Using Gas Heat, Hot Water, and Central Electric A/C (SF-1)

--------

7//// f’// //n

m

(If c! MISC

Eler!r, c t, & Electrfc

Load

C*, LJle

~

Electr(c

E . ,, ., A,r (,ondmoner

i P , .,

.“J,,+, . -t ~

tieamg

or

Cooling

,.. r, Load

,.. >, t. . . . .

D

Gas

Gas --1-- -* Fur~aw

“J, - !-

1

I

I

I

L J

A. ITEMIZED COST OF COMPONENTS

I

—

Ill

IL-- ——rWl[ .-. .-.

1

Ilw

,:.--%— ~-t&tral

T. f‘ —.., -— —. Alr Condltlonmg

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dobs)b”’

ICossventkxsoi reference system is SF-1)

1. Gos furnace . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45M Btih 15 $/M Btuh $675 0

2. DvCtio&................,.,............................................ . . . . . . . . . . . — — 425 ;:

3. Central electric o/c . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .1.85 tons 430 $/tOn 796 $3: 10

4. Gas water heater . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 gal 225 ea. 225 0 15

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $2,121 S30

ANNUAL ENERGY FLOWS (Conventional reference system is SF-1)

Energy COSISUISlOd Backup consumed W/ Energy SOVOCk

by ref. system wksr/cOnsewatiOsl (% of rotill

Net Electricity (bought-sold) (MWh/unit)..... . . . . . . . . . . . . . . 11.3 11.3 0.

hel consumed onsite (MMBN/wit)..... . . . . . . . . . . . . . . . . . . . . . 164. 164. 0.

Total energy requirenwnt (bfsl CA equiv.p . . . . . . . . . . . . 62. 62. 0.

Electricity sofd to grid annudy (MWh,entire buiMiW)........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.

Annual peak electricity demond (kW, entire kiMi~)......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.2

-“ Escobtion of conventicd energy costs

Ca+lstont red Enqy price Energy pcice

energy prices escabtion I escabtbn II

1. 1976 Storiup

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 116. (128.) 153. (165.) 226. (238.)

Total with 207. IT..........., . . . . . . . . . . . . . . . . . . . . . . . . . . 116. (128.) 153. [165.) 226. (238.)

Tohsl with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 J6. (128.) 153. (165.) 226. [238.)

2. 1985 Startvfsd

(capitol rebted Costs)......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

1~“ & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . .

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (electric bill] . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Totcsl with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 207. ITC............ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Totssl with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

29.

3::

48.

116.

116.

116.

[41.) 29.

[4.) 4.

(36.) 73.

(48.) 67.

(128.) 173.

(128.) 173.

(128.) 173.

(41.) 29.

(4.) 4.

(73.) 108.

(67.1 146.

(185.) 287.

(185.) 287.

(185.) 287.

[41.)

(4.)

(108.)

(146.)

[2W.)

(299.)

[299.)

C EFFECTIVE COST OF ENERGY TO CONSUMER

[C.mlventioncsl refec’essc e system is SF-1)

Type of incentives given

Levelized cost of sobf energy No FIJI!

of ‘Consewcstim’ ene~ incentives 20% ITC incentives

$/MMBtu pfiMOrY fad.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . N / A (N/A) N / A (N/A) N / A (N/A)

C/kWh ektii~......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . N / A (N/A) N / A (N/A) N / A (N/A)

Escobtion of conventional energy cosh

Constant red Energy price Energy price

Levdizedpica paid for conventicnwl WW#” energy prices ● ecobtion I escabtion II

$/MhfBtu primmy #.... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.37 4.86 7.80

C/kWh -"V.,.............,...........,.....,............ 3.97 5.73 9.18

-h

aJ
Table lV-2.—Albuquerque: Conventional System- Single Family House Using Improved Gas Heat, Hot Water, and Central Electric NC

\ r t

I

— -------

a H’-% Outside

I Heat Exchanger

I

DEL “%.,— ., -– -’ Alr-Condtllonlng

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (DoJhws)b’c A. ITEMIZED COST OF COMPONENTS

(Conventional reference ~ystem is SF-1)

Escalotiem of conventional energy costs Unit First cost Annual Lif e

Comcsonent - Siz e cost find. O&P) O&M (yrs)

constant mcsl Energy price Energy price

1. Gas furnace.. . . . . . . . . . . . 45M Etuh 17 $/M Btuh $765 wserav micas escalaticm I escokction II 0

2. Ductwork.. ,.,, ..; . : :.. :..;:: — — 425 ;;

3. Central electric oic . ., . . . . . . . 1.85 tons 430 $/ton 796 $3: ?0

4. Go! woter heater . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 gal $275 ea. 275 0 15

1. 1976 Stortup

a. Costs uiing *r (conservation) system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Totol with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Cosh using conventiww{ reference syshwn.. . . . . . .

2. 1985 StOrtUPd

o. Costs using solssr (conservation) system:

[copital related costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

(operation & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . .

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Costs using con.entiod reference wstem. . . . . . . .

111. (123.)

111. (123.)

110. (122.)

!Iz

143. (155.)

142. (155.)

142. (154.)

IS4.

210. [223.)

210. (223.]

210. [222.)

226.

TOTAL... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $2,261 $30

31. (43.)

(4.)

2:: (28.)

48. (48.)

111. (123.)

111. (123.)

110. {122.)

1 !Z

31. (43.)

4. (4.)

58. (58.)

67. [67.)

160. (172.)

1643. [172.)

159. (171.)

174.

31. (43.)

(4.)

8;: (85.]

146. (146.)

266. (278.)

266. (278.)

265. (277.)

287.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system is SF-I)

Type of incentives given

ANNUAL ENERGY FLOWS Levelized cost of solar energy No Full

or ‘conservation’ energy’ incentives 20% UC incentives (Conventional reference !ystem is SF-1)

$/MM6tu primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .61 (4.84) .53 (4.77) 43 (4.56)

@/kWh el~tiici~...... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .71 (5.70) .62 (5.62) .51 (5.36)

Escolaticm of conventional energy costs

Constant real ‘ Energy price Energy price

Levelizedpnke paid for conventional energ#’ “ energy prices escalation I escalation II

$/MMBtu prinwy fuel. . . . . . . . . . . . . . . . . . . . . . 3.37 4.86 7 8 0

t/k Wh ekctriri?y..... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.97 5.73 $? ?8

Energy consumed Backup consumed w/ Energy mved

bv ref. svstem solar/cOosamatiOn (% of totol)

Net Electricity (bought-sold) (MWh/unit)..... . . . . . . . . . . . . . . 11.3 11.3

Fuel consumed onsite [MMBtu/unit)... . . . . . . . . . . . . . . . . . . . . . . . 164. 129. 21t

Totol energy requirement (bbl crude equiv.j’ . . . . . . . . . . . . 62 54. 11.9

Electricity wld to grid annually (MWh,entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Annual peak electricity demand (kW, entire bildiW)........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5°2
Table IV.3.-Albuquerque: Conventional System— Insulated Single Family House Using Gas Heat, Hot Water, and Central Electric NC

Gr,c M 5(

FIPC*,,C ly I + [1?{ 11’[

, (dd A:-”;”-””---y\

=,,. I r I ,! .

L,

,!

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. -

-., ! . . ,

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Y

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////’// ,’,’ / //’f

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-- + L..l< tiw ,,W + 1 CMd Ii?<,!, k_ ---- “- “- - { Gas Absorptio n

I Alr-Cond!tlontng J

“L_L.E.l ~

A. ITEMIZED COST OF COMPONENTS B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars) b

’

c

(Conventional reference system is SF-1)

Unit First cost Annual Life

Component Size Co$t (incl. O&P) O&M (yrS)

1. Gos furnace . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31 M Btuh 15 $/M Btuh $465 0 15

2. DucWoti. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 425 30

3. Central ● lectric cc/c . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.3 tons 430 $/ton 559 $3: 10

4. Go! water kater............................................................, 40 gal 225 ea. 225 0

5. Extra insulation, storm doors and windows............., . . . . . . . . . — — 981 0 ;;

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . S2,655 $30

Escalation of conventional ● ergy costs

Constant red Energy price Energy price

energy prices e~alation I ● scalation II

1. 1976 Startup

a. Ca\ts usina solar (conservation) swtem:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 106. (1 19.) 136. (149.) 201. (214.)

149.) 200. (213.)

146.) 198. [21 1.)

Total with 20% ITC.,...................,....................

Totol with full iccccntives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Costs usi~ comwn/icmol reference system . . . . . . . .

2. 1985 Stortup~

0. Costs using solar {conservation) system:

(capitol rebted casts . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

(operation & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . .

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total with no incentive~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20?4 ITC...........................,..............

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Cosh using conventional reference system . . . . . . . .

105. (1 19.) 135.

103. (1 16.) 133. 116. 1s3, 226.

[43.) 30. (43.)

(4.) (4.)

(54.) d: (so.)

[65.] 140. (140.)

166.) 254. (267.)

165.) 253. (26&)

162.) 251, (264.)

287.

30. (43.)

4. [4.)

26. (26.)

46. [46.)

106. (1 19.)

105. (1 19.)

103. (1 16.)

116.

30.

4.

54.

65.

153.

152.

150.

173

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(conventional reference system is SF-1)

Type of incentivm given

Levelized cost of sokar energy No Full

w ‘Ccmwvation’ emelcJ# incentives 20% ITC incentives

$/MMBti primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

.22 (3.38) .01 (3.21) -.45

$/kWh e&tiici~....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

[2.62)

.26 [3.98) .02 (3.77) -.54 [3.08)

Escofation of conventional energy costs

Constant reel Energy price Energy price

levelixedprice paid fbr ccmve.fional ener&” energy prices escabtion I escobtbn II

$/XfMBtu p“maly fill. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.37 4.86 Z80

t/k Wh etitii~............................................., 3.97 5.73 9 1 8

ANNUAL ENERGY FLOWS (Conventional reference system is SF-1)

Energy conwmed Backup consumed w/ Energy saved

by ref. system sobr/corrsewation (% of totall

Net Electricity (bought-sold) [MWh/unit)... . . . . . . . . . . . . . . . . 11.3 10.7 4.9

Fuel consumed onsite (MMBtu/unit).., . . . . . . . . . . . . . . . . . . . . . . . 164. 121. 26.4

Total energy requirement (bbl crude equiv.~ . . . . . . . . . . . . 62. 51. 16.8

Electricity sold to grid annually (MWh,entim building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.

Annwl p.ak electricity demand (kW, ● ntire biMiW)................................................................., . . 4.3
Table IV-4 .—Albuquerque: Solar Hot Water System—Single Family House Using Flat-Plate Collectors (1977 Prices);

Building Equipped With SF-I Space-Conditioning

-— -----— ,= . -.

+t++i+++t

—-.

.,,

~

-—— .8

G

Ii I

II 1 Hl; !+>>’

% II )!1 \

.K-

--_=rJ Izzz u

\

Outside

! . Heat Exchanger

\

‘!

-—,, , Hot Water Storage

— . .‘/ with Gas BackuD .( ‘/- 1~---!=-’= ‘

--=== 

- -

Central

1- 1

1

Alr Condltlonlng

—-—- Compressor

8. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars) bc

(conventional reference system is SF-1)

A. ITEMIZED COST OF COMPONENTS

Unit Fir!t cost Annual life

Component Size cost (incl. O&P] O&M (ylS)

1. Gas furnace.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45M Btuh 15 $/M Btuh $675 0 15

2. Ductwork. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 425 30

3 Central electric OIC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 tons 430 $/ton 796 $3: 10

4. Hot water storage with gas fired backup (including hoot 100 gal $380 380 0 30

exchanger).

5. Pumps and control . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — $250 250 0 10

6 Inwlated steel pipe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 75 ft S2.6/ft 195 0

7 Flat plate !olor collectors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 m’ 143 $/m’ ’71 5 0 X

——Collector cost @ 95 $/m* “715 o 15

——lnftallation @ 16 $/m’

——Transportation @ $ 3/ins

——Overhead ond profit= 25%

TOTAL. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $4,151 S30

Escalation of conventional energy costs

COostOnt real Energy price Energy price

energy prices escokrtion I mcalation II

1. 1976 Stortup

a. Costs u$ing Am (conwvation) system:

Totol with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Totol with full incentiv** . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Cosh using conventional refemrua system . . . . . . . .

2. 1985 startup~

0. Cost* using dar [conservotian) syMem:

(capital related costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

[operation 6 maintenance costs) . . . . . . . . . . . . . . . . . . . . . . .

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . [electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Totol with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with full incentive . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Costi using conventtbrd referwwo SYSM........

127.

124.

120.

117.

148.)

146.)

136.)

157. (178.)

154. [176.)

150. [166.)

1s4.

224. (244.)

220. (242,)

216. (232.)

226.

50.

2::

48.

127.

124.

120.

1 ?7

(71.)

(4.)

(25.)

(48.)

148.)

146.)

136.)

50. (71.)

(4.)

5:: (52.)

67. (67.)

174. [195.)

170. (192.)

50. (71.]

(4.)

7:: (77.) 146. (146.)

277. (298.)

274. (295.)

270. (286.)

28Z

166. i182.j

174. s’ —. o

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference ~ystem is SF-1)

● % installed collectOr cost assumed replaced m 15 yrs., with total replacement in 30 yra.

ANNUAL ENERGY FLOWS

(Conventional reference system it SF-1)

Energy COnSUIWd BmkUp cmwmed wi En@wY $aved

by ref. system salar/can9ervatiti (% of total)

Net Electricity (bought-sold) (MWh/unit].........., . . . . . . . . 11.3 11.3 0.

Fuel conwned onsite (MMBtu/unit)... . . . . . . . . . . . . . . . . . . . . . . . 164. 117, 28.7

Total energy requirement (bbl crude .quiv.p . . . . . . . . . . . . 62. 52. 15.9

Electricity sold to grid onnually (MWh,ontire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o.

Annual peak electricity d.mcmd (kW, entire &iMing).. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.2

Typa of incentives given

Levelized cost of solar energy No Full

or ‘conservation’ energy’ incentive$ 20% ITC mcentwes

$/MMh pICICItY fuel.............................,........ 5.33 (10.64) 4.50 (9.94) 3.41 (7.58)

C/kWh ektiici~....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.27 (12.53) 5.30 [1 1.69) 4.01 [8.92)

Escalation of conventional energy costs

Constant real Energy price Energy price

levelizedprice paid for conventional eneq$ ‘ energy prlce~ escalation I escalation II

$/hfMBhI primmy fuel. . . . . . . . . . . . . 3 3 7 4.86 7.80

g/k Wh electricity......, . . . . . . . . . . 3 9 7 5 7 3 9.18

.— ——
Table lV-5.—Albuquerque:So[ar Hot WaterSystem—Singie Family House Using Flatiplate Collectors(Possible Future p~ceL

Building Equipped With SF-1 Space. Conditioning

-———--—- >.O r.

.,, ,

~ -

— - < r.

c l r-l---.: ~

I I

I

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-

- -

. ;

.\ ,’ !-v,

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—

1 --- - ‘“,

,.

Sodr

,! ..-,

PC, ”

L--r————

A. ITEMIZED COST OF COMPONENTS

Unit First cost

Component Size

Annuol Lif e

cost (iK1. O&p) 06M (yrs)

1. Gas furnace . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45M Btih- 15 $/M Btuh

2. DuctioA..........................................................,,,..,,.,,,, —

$675

3. Central electric cI/c . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 to”$

— 425 ; ;;

430 $/ton

4. Hot water storage with EIOS fired backup (including heat 796 $30 10

100 gal $380 exchanger). 380 0 30

5. Pumps and control. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — $2543

6. Insulated steel pipe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 250 0

75 ft $2.6/ft ;: 7. Flat plate solar cdktors................................................., 195

10 ma 86 $/m’ ’430 ;

—Collector cost @ 543 $/ml ’430 o H

——installation @ 16 $/m’

—-Tronspcwtotion @ $ 3/m~

—0.erhecid and profit= 25%

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $3,581 $30

● $$ installed collector cost owumed replaced in 15 yrs., with total replacement in 30 Yrs.

ANNUAL ENERGY FLOWs

(conventional reference svstem i. SF-11

, - -. .,

Energy COllW’ned

by ref. system

B~kup c~wmed W/ Energy saved

sOlor/c0n8ewatic.n (% of totol)

Net Electrici~ (bought-sold] (MWh/unit]........,,,.,,.,,.. 11.3 Fuel consumed onsite (MMBtu/unit)...,,,,,,,,,,.,,.,,.,,.,, 11.3

164. Total energy requirement (bbl crude equiv.p . . . . . . . . . . . . 117. 28!

62. 52. 15.9

Electricity sold to grid onnuolly [MWh,entire buikfing).................,,,,...,,.,,.

AIWWOI peek dectricity d.mand (kW, entire kiuiW),,,.,..,..,,,,.....,.,,,.....,,J""""""""""""""""""""""""""`""""""`"""" ““”””

. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5;

I 1(11111 Jl_Jl II 1! -!l Ik+=+J I

. Hot Water Storage

with Gas Backup

x~r—J

Alr-Condltlonlng

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (DOkIrS)b.c

(Conventional reference system is SF-1)

Escalation of conventional eneWy costs

Ccmstont real Energy @CO Energy price

● nergy prices e8colation I escalation II

1. 1976 Startup

a. Costt using *r (conservation) system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 122. (140.)

Total with 20% ITC............,..................,.,,..,.,,.

Total with full incentives

119. (138.)

. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 116. (131.]

b. Cosh using conventional mfemnce system . . . . . . . . 117.

2. 1985 Stccrtup~

cc. Costs using sdor (cometwcction) system:

(capitol reloted cOitd...........................,.,.,,..,..,,

(operotion & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . .

[fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

TOtal with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total with 20% ITC..............................,,,,.,,,....

Totol with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Costs using conventional mfbmnce s~~m. . . . . . . .

44. (62.)

4. (4.)

25. (25.)

48. (48.)

122. (140.)

119. (138.)

116. (131.) 117.

C. EFFECTIVE COST OF ENERGY TO

151. (170.) 218.

149.

(236.)

[168.) 215.

146.

(234.)

[161.) 212.

134.

(227.]

226.

44. (62.)

[4.)

5:: (52.)

67. (67.)

168. (186.)

165. (184.]

162. (177.]

174.

44. [62.)

4. (4.)

77. (77.)

146. [146.)

271. (289.)

269. (287.)

266. [281.)

287.

CONSUMER

(Ccmventicmol reference system it SF-I)

Type of incentives Oivm

Levelized cost of solar enerW No

or ‘consefvcction’ efcerg~ Full

incentives 20% ITC incentives

$/MMBtU timOIY fad...............,...................,. 3.83 (8.46) C/kWh ktici~............................................, 3.23

4.51 (9.95)

(7.95) 2.45

3.80

(6.25)

(9.35) 2.88 (7.36)

Etcobticm of cocwentiotd ● nergy cosb

COnstont real le.elized&c paid h cOn.entiWM/ ene#.* Energy price Energy prim

~tices escobtion I escabticm II

$/MhfBfcl fwhczry fowl....................................,. 3.37

t/kWh Atii~.......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.86

3.97

7.80

5.73 9.18
Table IV-6.—Albuquerque: Solar Hot Water and Heating System— Single Family House Using Flat-Plate Collectors (1977 Prices),

Low. Temperature Thermal Storage; Building Equipped With SF*1 Space. Conditioning

.-T

[

–7

~ - — —, ——

I “m /

——

\ <

‘L J

\

/ ’

‘,- — + . – — – “

 ––<’~~ ,

,’

-— —— —--- I

~--------1 \ r= 7

—..

-..

.—

[---:

Compressor

A. ITEMIZED COST OF COMPONENTS B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b

”

c

(Conventtonai reference system is SF-1)

Unit First cost Annual Life “

Component Size cost [incl. O&P) O&M (yr,)

1. Gas furnace . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2. Central electric 0/c . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

3. Ductwork . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 Collectors ond osmcmted costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

——Collectors @ 95 $/mz

——installation @ 16 $/ml

——Transportation @ 3 $/m’

——25 % overhead and profit

5 ?’4” insulated steel pipe . . . . . . . . . . . . . . . . .

6. Storage (without plumbing) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 Pump, control~, and heot exchanger........ . . . . . . . . . . . . . . . . . . . . . . . .

45M Btuh 15 $/M Btuh $675 15

1.85 tons 430 $/ton 796 $3: 10

— — 425 0 30

45 m’ 143 $/mz ● 3,218 o 15

● 3.218 o 30

125 ft $4.1 513 0 30

200 kWh $2.05/kWh 410 0 30

— S650 650 0 10

TOTAL.... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $9,905 $30

● Y2 Installed collector cost atwmed replaced In 15 yrs., with total replacement in 30 Yrs

ANNUAL ENERGY FLOWS

[Conventional reference system is SF-1)

Energy consumed Backup consumed w/ Energy saved

by ref. system sOlOr/conservation (% of total)

Net Electricity (bou~~old) (MWh/unit).. . . . . . . . . . . . . . . . . . 11.3 11.3

Fuel consumed onsite (MMBtu/unit).. . . . . . . . . . . . . . . . . . . 164. 42. 74: ;

Total energy requlremwct (bbl crude equiv.y . . . . . . . . . . 62. 36. 41,0

Electricity sold to grid annually (MWh,entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Annual peak electricity demand (kW, entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ● 5°2

E*colotion of conventional energy costs

Constont real Energy price Energy price

energy prices escalation I escalation II

1. 1976 Startup

a. Costs using solar [conservotlon) system:

Total with no incentive$. . . . . . . . . . . . . . . 173. (222.) 192. (240.) 248. [297.)

Total with 20% IT.. . . . . . . . . . . . . . . . . . . . . 161. (21 1.) 179. (230.) 236.

Total with full incentives

(286.)

. . . . . . . . . . 144. (175.) 163. (194.) 219.

b. Costs using conventional reference system. . . . . .

(250.)

I 17. 154. 226.

2. 1985 Startup d

o. Costs using solar (cOnse~at!On) system.

(copital related costs).... . . . . . . . . 112. (160.) 112, [160.) 112.

(operation & maintenance costs)

(160.)

. . . . . . . . 4. (4.) [4.] 4.

[fuel bill) . . . . . . . . . . . . . . . .

(4.)

. . . . . . . 9. (9.) 1;:

(e(ectric bill) . . . . . . . . .

(19.) 28. [28.)

48. [48.) 67. (67.) 146. (146.)

Total with no incentive! 173. [222.) 202. (251.) 290.

Totol with 20% ITC

(338.)

161. (21 1.) 190. [240.) 277 (328.)

Total with full incentives 144. [175.) 173, [204.) 261 (292.)

b. Costs using conventtonol reference system 117. 174. 287

C. EFFECTIVE COST Of ENERGY TO CONSUMER

[Conventional reference system is SF-1)

Type of incentives given

Levehzed cost of solar energy No Full

or ‘consewation’ energy” incentive 20% ITC Incentives

$/MMBtu primary fuel. . . . . . . . . . . . . . . . . . . . . . . . 8.15 (12.93) 6.92 [11.B8) 5.30 (8.37)

e/kWh electiiciw. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9.60 (15.22) 8.14 (13 98) 623 (9 85)

Escolotion of conventmnal ● nergy costs

Constant real Energy price Energy price

levelizedprice paid for conventional energ~ ‘ energy prices escalation I escalation II

$/MM8iCI prinw~ fuel., . . . . . . . . . . . . . . . . . . . . . . . . 3 3 7 4.86 780 “—

~/k Wh electricity . . . . . . . . . . . . . . . . . . . . . . . . . . 3 9 7 5 7 3 9 1 8
Table IV-7.—Albuquerque: Solar Hot Water and Heating System— Single Family House Using Flat-Plate Collectors (Possible Future Price),

Low-Temperature Thermal Storage; Building Equipped With SF-1 Space-Conditioning

Grid MISC

Electrc,ly Electrlc

Load

-------- Fuel Line

AC Electr c N

+++t+M+ ‘C’’’’’’’”

W.ler L .,s

P

~ A ‘“CI

MM E.cnmqe,

E@------: I

Electrtc

+

A(r1 Condtt(oner

I

7 I

Heating

or

Flat Plate I

solar

Cooltng

Collector /

Load

1 r L ----- -

r

Gas

Backup

I Furnace

I h Hot Waler I

Storage — 1

120 200” F 4

,1 I

Water Domest(c

supply

HW HW — Load

IGas Backup

.– 05)

1

A. ITEMIZED COST OF COMPONENTS

Unit First cost Annual Life

COmmxwsnt Size cost (incl. O&P) O&M (yrs)

1. Got furnace . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2. Control electric a/c . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3. Ductwork . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

4. Collectors and associated costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

—Collectors @ 50 $/m*

—Installation @ 16 $/m’

—Transportation @ 3 $/m’

—-25% overhead and profit

5. %“ insulated steel pipe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

6. Storage (without plumbing) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

7. Pump, controls, and heat exchanger . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

45M Btuh 15 $/M Btuh $675

1.85 tons 430 $/ton 796 $3;

— — 425

45 ma 86 $/m’ ● 1,935 :

● 1,935 o

125 ft $4.1 513

200 kwh $2.05/kW h 410 :

— $650 500 0

TOTAL... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $7,189 $30

30

30

10

● ?4 installed collector cost assumed replaced in 15 yrs., with total replacement in 30 yrs.

ANNUAL ENERGY FLOWS

(Conventional reference system is SF-1)

Energy consumed Backup consumed w/ Energy saved

by ref. system solar/conservation (Y. of total)

Net Electricity (bought-sold) (MWh/unit). . . . . . . . . . . . . . . . . . . 11.3 11.3 -. 1

Fuel consumed onsite (MMBtu/unit) . . . . . . . . . . . . . . . . . . . . . . . . . . 164. 42. 74.1

Total energy requirement (bbl crude equiv.r . . . . . . . . . . . . 62. 36. 41.0

Electricity sold to grid annually (MWh,entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.

Annual pecrk electricity demand (kW, entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.2

// \\ \ \ \ \

.zn---=s\ \

I I

A \

Outside —

Heat Exchanger

h

Furnace

&

{

& Water to Air Hot Water

Heat Exchanger Storage

— Air-Conditioning

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dohm)b’c

(Conventional reference system is SF-1)

Escalation of conventional energy costs

Constant real Energy price Energy price

energy prices escalation I escalation II

1. 1976 Startup

o. Casts using solar (cansetvation) system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 144. (179.) 163. [198.) 219. (254.) Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 136. (172.) 154. (191.) 211. [247.) Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125. (149.) 1 4 . (168.) 200. (224.)

b. Costs using cmrventiosrcd mfeswnce system . . . . . . . . 117. 154. 226.

2. 1985 Stortupd

a. Costs using solar (conservation) system:

(capital related costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 82. (118.) 82. [1 18.) 82. (1 18.)

[operation & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . . 4. (4.) 4. (4.) (4.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (9.) (19.) 2;: [28.)

(electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2: (48.) i;: [67.) (146.)

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 144. (179.) 173. (208.) H (296.)

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 136. (172.) 165. (201.) 252. (289.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125. (149.) 154. (178.) 242. [266.)

b. Costs using conventional mbmnce sys~m . . . . . . . . 117. 174. 287.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system is SF-1)

Type of incentives given

Levelized cost of solar enemy No Full

or ‘consewaticm’ energ~ incentives 20% ITC incentives

$/MMBtu primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.27 [8.76) 4.47 (8.07) 3.41 (5.79)

VkWh elmtiiciW . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.20 (10.30) 5.26 (9.50) 4.01 (6.81)

Escalation of conventional energy costs

Constant real Energy price Energy price

levelizedptice paid for conventiorrol erresg~.e energy prices escalation I escalation II

$/hfM8hs P“mary rid.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.37 4.86 Z80

$/kWh ehtiki~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.97 5 7 3 9.18

-.

Y-
--------

c l

Table IV-8.—Albuquerque: Conventional System— Single Family House Using Oil Heating and Central Electric A/C (SF-5)

,J, . . .

: ,, ,

~ , , ., L . ,- ! . ,,. ,

.,

,$, . .

. . . , , ,.

,>

El- Fuel F ,r-a L,

.

. . . . 0,1 ‘-

~ ‘— .-

.

I

I

I

,’” :,. l-_ * ) -,~,

1 .: , , .W + L ,,

w He,?.!?,

.— ,

I I

A. ITEMIZED COST OF COMPONENTS

Unit First cost Annual Life

Component Size cost (ind. O&P) O&M (yrs)

1. Oil furnac e.. . . . . . . . . . . . . . . . . 45M Btuh 23 $/M Btuh $1,030

2. Ductwork . . . . . . . . . . . . . . . . . . . . . . . . . . ...:.,.:.. —

$30 15

— 425 0 30

3. Centd electric o/c . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 tom 430 $/ton 796 30 10

4. Gas hot water heater.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 gol 225 ea. 225 0 15

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $2,476 $60

ANNUAL ENERGY FLOWS (Conventional reference system is SF-51

Energy consumed BOCkUp CO. WTWM4 W/ Energy saved

by ref. system dar/conservation [% of total)

Net Electrici~ (bought.~) (MWh/unit). . . . . . . . . . . . . . . . . . . 11.5 11.5 0

Fwel consumed otwite [MMBtu/unit) . . . . . . . . . . . . . . . . . . . . . . . . . . 205. 205. 0,

Total energy requirement (bkd crude equiv.~ . . . . . . . . . . . . 71. 71. 0.

Electricity sold to grid annually (MWh,entire buildim) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o.

Annual peak electricity Anmnd (kW, ● ntire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.2

\

. . .

‘-? \.r -. .f Alr Cond(tlonlng

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars) b’

c

[Conventional reference system is SF-5)

Exolation of conventional energy costf

Constont real Energy price Energy price

energy prices escalation I escalation II

1. 1976 Stortup

—

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 179. (193.) 212. (226.) 358. (372.)

Totol with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 179. [193.) 212. [226.) 358. (372.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 179. (193.) 212. [226.) 358. (372.)

2. 1985 Startupd

(capitol related costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

[operat”a 6 maintenance costs).. . . . . . . . . . . . .

(fuel bilf) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

(electric billl . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20% IT.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . .

33. [47.)

(9.)

Ill [88.)

49. [49.)

179. (193.)

179. (193.)

179. (193.)

33. [47.) 33. (47.)

9. (9.) 9. [9.)

120. (120.) 268. (268.]

68. M.) 14s. [148.)

230. [244.) 4s8. (472.)

230. (24.) 458. [472.)

230. [244.) 45& (472.)

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system is SF-5)

Type of incentives given

Levelized cost of Ax emergy No Full

or ‘conservation’ energy’ incentives 20% ITC incentives

$/MMBtu prima~ f~l.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . N / A (N/A) N / A [N/A) N / A [N/A)

C/kWh ektrici~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . N / A [N/A) N / A (N/A) N / A (N/A)

Escalation of convent!onol energy costs

Constant real Energy price Energy pr!ce

[evehxedprke paid for conventional enq+’” energy prices escolatfon I escalation II

$/MAt8hI primqy fuel.... . 4 8 2 5. w / 1 /5 –

&’kWh eh~@.. . . . 5.67 7.05 13.12
Table IV.9.–Albuquerque: Conventional System–Single Family House Using Improved Oil Heating and Central Electric A/C (SF-5)

.-- .-—--

c l

r

Gr c

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EIe@r c ‘, Elerlr(c

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. .

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D

Fuel 011

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:,

I

I

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58,[,~ . Hw k Load

Healer

‘~ 05

A. ITEMIZED COST OF COMPONENTS

Unit First cott

Component

Annuol Lif e

Size cost (incl. O&P) O&M (yrs)

1. Oil fumoce. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45 M Btuh 25 $/M Btuh $1,120 $30

2. DuctioA....................................................,.......... . . . . . . . . . . . — — 425 0 H

3. Central electric a/c . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 tons 430 $/ton 796 30 10

4. Gas water heater . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 gal $275 ea. 275 0 15

TOTAL., . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $2,616 $6o

ANNUAL ENERGY FLOWS

(Conventional reference system is SF-5)

Energy consumed Backup consumed w/ Energy saved

by ref. syttem 5010r/conservation (% of total)

Net Electricity (bought-sold) [MWh/unit) . . . . . . . . . . . . . . . . . . . 11.5 11.9 -3.5

Fuel consumed onsite [MMBtu/unit) . . . . . . . . . . . . . . . . . . . . . . . . . . 205. 161. 21.4

Total energy requirement (bbl crude aquiv.y . . . . . . . . . . . . 71. 63. 11.5

&--ii-”--\

(’,,-’‘1 -—

‘i -f- – Central -— . —.. -—

Alr-Condltionlng

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars) b,

c

(Conventional reference system is SF-5)

Escalation of conventional energy costs

Constant real Energy price Energy price

energy prices e$colation I escalation II

1. 1976 Startup

0. Costs using solar (conservation] system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 163. (178.) 192. (207.) 320. (334.)

Total with 20% ITC................., . . . . . . . . . . . . . . . . . . . . . . . . 163. (177.) 192. (206.) 319. (334.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 163. (177.) 192. [206.} 319. (333.)

b. Costs using conventional reference system . . . . . . . . 179. 212. 358.

2. 1985 Startupd

a. Costs tmirig aokcr (conservation) aystem:

(capital reloted casts....................................,.

(opemtion & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . .

(fwal bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20% ITC..............................,...........

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Costs using conventional reference system . . . . . . . .

35. [50.)

9. [9.)

69. (69.)

50. (50.]

163. (178.)

163. (177.)

163. (177.)

179.

35. [50.)

9. (9.)

94. (94.)

70. (70.)

208. (223.)

208. (223.)

208. (222.)

231.

35. (50.)

9. (9.)

211. [21 1.)

152. (152.)

407. (421.)

406. (421.)

406. (420.)

4s8.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system is SF-5)

Type of incentives given

Levelized cost of sokar energy No Full

of ‘consewotion’ energf incentives 20% ITC incentives

$/MMBtu primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .54 (4.94) (4.89) .39 [4.69)

t/kWh ektiici~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .64 (5.82) :: (5.75) .45 (5.52)

Escalation of conventional energy costs

Corwtant real Energy price Energy price

Levelizedpnre paid for conventional enet-g~e energy prices escalation I e5c010ti0n II

Electricity dd to grid annually (MWh, entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o.

Annual peak electricity demand (kW, entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.2

$/MMBtCI primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.82 5.99 11.15

VkWh elec~rity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.67 7.05 13.12
Table IV.lO.— Albuquerque: Conventional System— Insulated Single Family House Using Oil Heating and Central Electric A/C (IF-5)

————— —-—

1 r

c1

. .

,, .

F , ~ ,

+

1 I

c1.. , .

.,Et--,--u “

I

A. ITEMIZED COST OF COMPONENTS

Unit First cost

Component Size cost [incl. O&P)

1. Oil furnace ,. 31M Btuh 23 $/M Btuh $713

2. Ductwor k — — 425

3. Central electric a/c . . . 1.3 tons 430 $/ton 559

4 GaJ woter heater . . . . . 40 gal 225 ea. 225

5. Extra insulation, storm doors and windows . . . . . . . . . . . . — — 981

Annual

O&M

Life

(yrs)

$30

0

30

0

0

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $2,903 S60

ANNUAL ENERGY FLOws (COnV@iOnal reference system k SF-5) —.

Energy consumed Bockup consumed W/ Energy SCIV~

by ref. system sOlOr/cOnsewatiOn ( ‘Va of @tlJ)

Net Electricity (boughtsold) (MWh/unit) . . . . . . . . . . . . . . . . . . . 11.5 10.7 6.5

Fuel consumed onsite (MMBtu/unit) . . . . . . . . . . . . . . . . . . . . . . . . . . 205. 151. 26.4

Totol energy requirement (bbl crude equiv.~ . . . . 71. 58. 18.5

Electr,c,ty sold to grid onnwdly (MWh, emtire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o.

Annwd peak electricity demand (kW, entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . 4.3

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011 L ----@-J:-,T ‘, Heat Exchanger ——>—;—

Furnace >,’

F--”’ ~

‘, &j-”<---

——

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~enlral

Alr COndltlOnln Q

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)bc

(Conventional reference system is SF.5)

Escalation of conventional energy costs

Constant real Energy price Energy price

energy prices escalation I escalation II

1. 1976 Startup

a. Costs using solar (cOnsematiOn) system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 153. (167.) 180. [194.) 298. (313.)

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 152. [166.) 179. (194.] 298. (312.)

Totol with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 150. [165.) 177. (192.) 296. (310.)

b. Costs using conventional mfemnce system . . . . . . . . 179. 212. 358.

2. 1985 Stortupd

0. Costs using solar (conservation) ~y~tem:

[capital related costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33. (47.) 33. (47.) 33. {47.)

(operation & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . . 9. (9.) [9.) 9. (9.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 65. (65.) 8;: (89.) 198. (198.)

(electric billl . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 46. (46.) 65. (65.) 140. (140.)

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 153. (167.) 195. (209.) 379. [394.]

Totol with 20% ITC.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 152. (166.) 194. (209.) 379. (393.)

Total with full incentive} . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 150. (165.) 192. (207.) 377. (391.)

b Costs using conventional reference system . . . . . . . . 179. 230. 458.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system is SF-5)

Type of incentive! given

Levelized cost of solar energy No Full

or ‘conservation’ energy’ incentives 20% ITC incentives

$/MMBfu primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . -.08 (2.69) -.21 (2.58) -.51 (2.21)

e/kWh electricity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . -.10 (3. 16) -25 (3.03) .60 (2 60)

Escalation of conventmnal energy costs

Constan; real Energy price Energy price

le.elizedpnre paid for con.ent!onal energ~ c energy prices escolatlon I escolotion II

$/MM6fu primary fuel. . . . . . 4 8 2 5 w- 11.15

t/kWh electricity..,. . . . 5 6 7 7 0 5 13.12
Table IV-11 .—Albuquerque: Solar Hol Water System—Single Family House Using Fiat. Plate Collectors (1977 Prices);

Building Equipped With SF-5 Space-Conditioning

J

A. ITEMIZED COST OF COMPONENTS

Unit fir~t cost

Component

Annual Life

Size cost [incl. O&P) O&M [y~]

1. Oil furnace . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 Ductwork . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

3. Central electric 0/c . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

4, Hot water storage whh electric backup (including heat

exchanger).

5 Pumps and control. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

6. Insulated steel pipe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

7 Flat plate solar collector~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

—Collector c05t @ 95 $/m’

——lrmtallotion @ 16 $/m’

——Transpartotion @ $3/m

—Overhead and profit= 25%

45M Btuh 23 $/M Btuh $1,030 S30

— — 425 0 :;

1.85 tons 430 S/ton 796 30 10

100 gal $380 380 0 30

— $250 250 0 10

75 ft $2.6/ff 195 0 30

10 m’ 143 $/ms

“715 o 30

● 715 o 15

TOTAL.,. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $4,506 $60

● V2 lnstolled collector cost assumed replaced in 15 yrs., with total replacement In 30 yrs

ANNUAL ENERGY FLOWS

(Conventional reference system is SF.5)

Energy consumed Backup consumed W/ Emsrgy saved

by ref. system salar/conservation (% of total)

Net Electricity (bught-dd) (MWh/unit). . . . . . . . . . . . . . . . . . . 11.5 11.3 1.7

Fuel conwmed onsite (MMBtu/unit) . . . . . . . . . . . . . . . . . . . . . . . . . . 205. 146. 28.7

Total energy requirement (bbl crude equiv.~ . . . . . . . . . . 71 5a. 18.0

Electricity sold to grid annually (MWh, entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.

Annual peak electricity demand (kW, entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.2

‘% -./ -—

-f Central

Alr-Condltlonmg

Compressor

B. LEVEIJZED MONTHLY COSTS PER UNIT TO CONSUMER (Dohs)bsc

(Conventional reference system is SF-5)

Escobtic+ of canventianal energy costs

Canstont real Energy pdCe Energy price

energy Pricei escobtion I escobtian II

1. 1976 Startup

a. Costl using salar (cansewaticm) sy~tenc:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Totol with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Cosh using conventional reference system . . . . . . . .

2. 1985 startup~

0. Costs uling sakar (conwrvatioct) system:

(capitol related costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

(operatian & maintenance costt) . . . . . . . . . . . . . . . . . . . . . . .

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 200/. IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

174. (197.)

171. (194.) 166. i185.i

179.

54. (77.)

[9.)

:: (63.)

48. (48.)

174. (197.)

171. (194.) 166. (185.)

201. (224.)

198. [221.)

194. (212.)

212.

54. (77.)

9. (9.)

B6. (86.)

67. (67.)

216. (239.)

213. ‘ (236.)

209. [227.)

319. (342.)

316. (339.)

312. (330.)

358.

54. (77.)

9. [9.]

191. (191.)

146. (146.) 400. (423.)

397. (420.)

393. [41 1.)

b. Cosh using conventional reference system . . . . . . . . 179. 231. 458.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system is SF-5)

Type of incentives given

Levelized cost of salor energy No Full

or ‘conservation’ energ~ incentives 20% ITC incentives

$/MM8ti primory fuel............., . . . . . . . . . . . . . . . . . . . . . . . . 4.10 [8s8) 3.46 (8.03) 2.62 [6.22)

$/kWh ektrici~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.83 (10.10) 4.08 (9.46) 3.09 (7.32)

E\colation of conventiaccal energy costs

Constant real Energy price Energy price

Levelksdp rice paid for conventional eneW#’e energy prices escalation I ● scalation II

$/MhfBhI PtimO~ fuel......, . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.82 5.99 11.15

t/k Wh ehtiiw . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.67 7.05 13.12
Table IV-12. —Albuquerque: Solar Hot Water and Heating System —Single Family House Using Flat-Plate Collectors (1977 Prices);

Low-Temperature Thermal Storage; Building Equipped With SF-5 Space-Conditioning

HR ‘L– “’—7

I

———————- . m-------

1-

I-=1

I

I ~—. f “— > = Alr-LonalIlonlng

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b+c

A. ITEMIZED COST OF COMPONENTS ICnnvssntional --- reference swtem is SF-51

Escolatic.n of conventional energy costs Unit First cost Annual Life

Size cost [incl. O&P) O&M [yrs) Constant real Energy price Energy price

energy prices escalation I escalation II

1 1976 Static!

Component

1 Oil furnac e . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45M Bt.h 23 $/M Btuh $1,030 $30 15

2. Centroi electric o/c . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 85 tons 430 $/ton 796 30

3. Ductwork . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — 425 0 ;:

4. collectors and associated costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45 m’ 143 $/ms ‘3,218 o

——Collectors @ 95 $/ml ● 3,21B o ;:

0. Costs using mlar (conservation) system:

Tohyl with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 196. [246.) 213. (264.] 289. (339.)

Total W~th 20% ITC.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

183. (235.) 201. (253.) 276. (328.)

Total with full incentwes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

167. (200.) 184. (218.) 260. (293.)

b. Costs using cossvenfsbnd mfemnce system . . . . . . . .

——installation-@ 179. 212. 358. 16 $/m*

—--Tronmwtation @ 3 S/m*

——25”/. ‘overhead~nd profit

5. %’4” insulat+ Iteel pipe . . . . . . . . . . . . . . . . . . . . . . . 125 f? $4.1

6. Storage [w!thout plumbing) . . . . . . . . . . . . . . 200 kwh $2.05/kWh

7. Pump, controls, and heat exchanger . . . $650 —

TOTAL. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

513 0

410 0

650 0

30

30

10

2. 1985 Statipd

0. Costs using solar (c0n8ewati0n) system:

(capitol related costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

(operation & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . .

(fuel bill) .:... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (electric ball) ............:. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with no incentwei . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b Cosh usina conventicmcd mfemnce system . . . . . . . .

116. (167.)

(9.)

3! (31.)

67. (67.)

223. [274.)

211. [263.)

194. (227.)

231.

116. [167.)

9. (9.)

69. (69.)

146. [146.)

340. (391.)

328. (380.)

311. (344.)

4s8.

116. (167.)

9. (9.)

23. (23.)

43. (43.)

196. (246.)

183. (235.)

167. (200.)

179.

$10,260 $60

C. EFFECTIVE COST OF ENERGY TO CONSUMER

[Conventional reference system is SF-5)

Type Of incentives given

. i/2 in~talled ~OlleCtO, ~O$t ~s~vm~ ~eplaCed i“ 15 y,,., With total replacement m 30 v

Levelized co~t of dor energy

or “c0n5ervati0n’ energ~

$/MMB~ pri~y fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

e/kwh electiiciW . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

No

incentives

6.42 (10.34) 5.45 [9.51)

7.56 [12.17) 6.41 (1 1.19)

Escalation of conventoonol energy costs

20% ITC

Full

ANNUAL ENERGY FLOWS incentive~

(Conventional reference system IS SF-5)

~

Energy consumed

by ref. syttem Wlor/conlewatiol’l (% of total]

JNet Elec~i~lfy [~vght,~d] (MWh/unit) . . . . . . . . . . . . . . . . . . . 11.5 11.3 1.7

Fuel ~o”,um~ ~“,ite OAMBtu/unit).......l . . . . . . . . . . . . . . . . . . 205. 53. 74.1

TotOl ~ne,gy ,equi,emgnt (bbi cmde equw.)’ . . . . . . . . . . . . 71. 39. 45.4

Electricity sold to grid Pnnuol& [MWh,entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o.

An””al ~ak ~l~tiiciw demond (kW, entire buiMing] . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.2

4.17 [6.75)

4.91 (7.94) —

constant real Energy price Energy price

Levelizedprike paid for conventional energ~e energy prices escalotlon I escalation II

$/MM8tu primqy fuel. . . . . . . . . . . . . . . . . . 482 5.9P 11 15

e/kWh electrici~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.67 7.05 1312
Table IV-13.-Albuquerque: Conventional System-Single Family House With Gas Heat and Hot Water and Gas-Powered Absorption A/C (IF-7)

.— —--—--

.

f ///////////

c1

F* I Lme

A C Elec!rlc IN

Grid

MISC

* Electrlc D C. E!(w 1, < II, ElectrlcKy Loads

A

Warer . ImIX.

tied! E. t,,qnc~erc

r

Gas

f

Absorption ,

‘.rhnf I

Chiller Heating

I

&

Cooling

I

Loads

B-:I

P——————

I

-1 Water --- - + Gas Hot

supply

Hot Water

P Water * Loads

Heater

A. ITEMIZED COST OF COMPONENTS

Unit First cost Annual Life

Component Size cost (incl O&P) O&M [yrs)

1. Gas furnace . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45 MBtuh 15$ MBtuh $675 $0 15

2 Ductwork . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 425 0 30

3 Central absorption A/C. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 tons 850 $/ton 1,570 20 15

4 Gas water heater . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 gal. 225 ea. 225 0 15

TOTAL FOR BUILDING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $2,895 $20

ANNUAL ENERGY FLOWS

[Conventional reference system is SF-7J

Energy COllSU# Backup canmmced w/ Energy saved

by ref. system salar/conservation (% of total)

Net Electricity (bought-sold) (MWh/unit). . . . . . . . . . . . . . . . . . . 8.0 8.0 0.

Fuel consumed onsite (MM5tu/unit) . . . . . . . . . . . . . . . . . . . . . . . . . . 218. 218. 0.

Totol energy requirement (bbl crude equiv.p . . . . . . . . . . . . 65. 65. 0.

Electricity sold to grid annually (MWh,entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o.

Annual peak electricity demand (kW, entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.5

.:’1 ~

p-- J!L-J

\

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b”

c

[Conventional reference system is SF-7)

Escalation of conventianccl energy costs

Canstant real Energy price Energy price

energy prices escalation I escalation II

1. 1976 Startup

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 122. (138.) lb5. [180.) 233. (249.)

Total with 20% IT.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 122. [138.) 165. (180.) 233. [249.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 122. (138.] 165. (180.) 233. (249.)

2. 1985 Startupd

(capital related cost.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35. (50.) 35. (50.) 35. (50.)

(operation & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . . 3. (3.) 3. (3.) 3. (3.)

[fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 47. (47.) 97. (97.) 143. (143.)

(electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37. [37.) 53. (53.) 114. [1 14.)

Total with na incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 122. (138.) 187. (203.) 295. [310.)

Total with 20% IT.,. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 122. (138.) 187. (203.) 295. (310.)

Total with full incentive~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 122. (138.) 187. (203.) 295. (310.)

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system is SF-7)

Type of incentives given

Levelized cost of salar energy No Full

or ‘conservation’ energy’ incentive 20% ITC incentives

$/MMBtu primary fuel...................................,.. N / A (N/A) N / A (N/A) N / A (N/A)

$/kWh electricity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . N / A IN/A) N / A IN/A) N / A fN/Al

Escalation of conventional energy costs

Constant real Energy price Energy price

Le.eiizedprire paid for conventional energ~,e energy prices escalation I escalation II

$/MM6ti primay fuel....................................., 3.25 4.87 7.51

e/k Wh eltitiici~. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.82 5.73 8.84
Table IV-14,

—-—.—-——

.,,

-Albuquerque: Solar Hot Water, Heating, and Cooling System— Single Family House Using Flat-plate Collectors (1977 Prices);

Low-Temperature Thermal Storage; Building Equipped With SF-7 Space-Conditioning

1. Gas furnace. .

2 Ductwor k

3. Absorption A/C.

4 Storciae tan k

A. ITEMIZED COST OF COMPONENTS

Unit Fir\t cost Annual Life

Component Size cost [incl O&P) O&M (yrs)

45 MBtuh 15$ MBtuh $660 $0 15

— — 425 0 30

I 85 tons 850 $/ton 1,570 20 15

. . , 200 kWh 2.05 $/kWh 410 0 30

5 Heat ;xchanger, pump, ond controls — — 650 0 10

6 Insulated steel pipe ., 125 ft. 4.1 $/ft. o 30

7 Flat plate solar collectors. 45 m% 143 $/mJ

.3218 0 30

——Collector cost @ 95 $/m’ .3218 0 15

——lnstallahon @ 16 $/m’

——Tronsportotion @ 3 $/ma

——Overhead and profit equals 25 percent

TOTAL FOR BUILDING .,.,.., . . . . . . . . . . . . . . . . . . . . . . $13,729 $2000

, Installed cr?lkz!or i-ust dssumed replaced In 1 5 yrs w,th total replacem?nf m 1[} yr%

ANNUAL ENERGY FLOWS

(Conventional reference !y,tem IS SF-7)

Energy consumed Backup consumed W/ Energy ~Oved

by ref. system salar/cansewcctiOn [% of total)

Net Electricity (baught-said) (MWh/unit). . . . . . . . . . . . . . . . . . . &o B.O

Fuel consumed onsite (MMBtu/unit) . . . . . . . . . . . . . . . . . . . . . . . . . . 218. 42. 80°7

Total energy requirement [bbl crude equiv.r . . . . . . . . . . . . 65. 2B. 56.2

Electmctty sold to grid annually (MWh, entire kildiW) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Annual peak electr!clv demand (kW, entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3:

A ‘

 - -’. 7 -.. ---

Oulslde

Heat Fxchanger

Hot Water

Storage Tank

Alr Condlt!onmg

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars) b’

c

(Conventional reference system it SF-7)

Escalation of conventional energy costs

Canstont real Energy price Energy price

energy prices escolotion I escalation II

1. 1976 Startup

0. Costs using solar (conservation) sy$tem:

Total with na incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 167. [219.) 1 B3. (235.) 228. (2B0.)

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154. (208.) 170. [224.) 215. (269.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 138. (173.) 154. (189.) IW. (234.]

b. Costs using conventional reference system . . . . . . . . 122. 165. 233.

2. 1985 Startupd

a. Costs using salar (conservation) system:

(capital related casts) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 117. (170.) 117. (170.) 117. (170.]

(operation 6 maintenance casts) . . . . . . . . . . . . . . . . . . . . . . . 3. (3.) 3. (3.) 3. [3.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9. (9.) 19. (19.) 28. (28.)

[electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37. [37.) 53. [53.] 114. (1 14.)

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 167. (219.) 192. (2U.) 262. (314.)

Total with 20% IT.. . . . . . . . . . . . . . . . . . . . . . . . . . . . 154. [208.) 179. (233.) 249. (304.)

Totol with full incentives . . . . . . 138. (173.) 163. (198.) 233. (268.)

b. Cofts using convent!onol reference system 122. 187. 295.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system is SF-7)

Type of incentives given

Levelized cast of s&r energy Na FuII

ar ‘conservation’ energyc incentives 20% ITC mcentwes

$/MMBtu primary fuel......, . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.64 (9.21) 4.7B (8 48) 3.66 (6.05]

C/kWh ~~trict~ . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.63 (10.83) 5.63 (99B) 431 (7 12)

Escolatlon of conventional energy costs

Constant real Energy price Energy price

levehzed price pad for conventional energ#’ ‘ energy prices escalation I escalation II

$/MhfL?tu primaty fuel. . . . . . . . . . . . 3 25” 4 8 7 751

t/k Wh elec?r]c(ty . . . . . . . “.’ ~~' 3 8 2 5 7 3 8.84
.- —— ----

/ / //1///// /

c1

Table IV-1 5.—Albuquerque: Solar Hot Water, Heating, and Cooling System—Single Family House Using Flat-Plate Collectors

(Possible Future Price), Low-Temperature Thermal Storage; Building Equipped With SF-7 Space. Conditioning

\ \ \ \

Gr@ MISC

Elecfrlcty Electr(c

Loads

Absorption

r

------ -

Choler

Solar

Thermal ‘1

Collectors I

t

I T

Ho! wale,

L

~

*

Slorage

I

m-:

I

- - - J\_/

Waler

I

I

Supp!y L

: :::X m “-.Y—. Gas Absorphon

Alr Condltlonlng

A. ITEMIZED COST OF COMPONENTS B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars) bc

(Convenfmnal reference system is SF-7)

Unit First cost Annual

Component

Life

Size cost (incl O&P) (XIM (yrs)

1. Gas furnace . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45 MEltuh 15 $ MBtuh $675 0 15

2. DucWoA............................................................,.. . . . . . . . . . . — — 425 0 30

3. Absorption a/c. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 tons 850 $/ton 1,570 $20 15

4. Storage tank . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 200 kWh 2.05 $/kWh 410 0 30

5. Heat exchanger, pump, and controls . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 500 0 10

6. Insulated steel pipe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125 ft. 4.1 $/f! 513 0 30

7. Flat plate \olar cdl~tor\. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45 m’ 86 $/m’ ‘ 1 935

—-Collector cost @ 50 $/m’

o 30

‘ 1 935 0 15

——ln$tollation @ 16 $/m:

—-Tronsportotion @ 3 $/m*

—overhead and profit = 25%

TOTAL....,....,.., . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $7,963 $20

. ‘ z installed collector cost assumed re~laced m 15 yrs w!th total replacement m 30 YTS

ANNUAL ENERGY FLOWS

(Conventional reference system IS SF.7)

.—

Energy consumed Backup consumed w, Energy saved

by ref system solorlconservatlon (“/. of total)

Net Electricity (bought-sold] (MWh, umt) 8.0 8 0 0

Fuel consumed o“sjte (M MBtu/u”lt) 218 42. 80.7

Total —— energy req”ireme”t (bbl crude eq”iv )’ 65 28. 56.2

Electricity sold to gr}d onnually (MWh,entlre bulld,ng) 0

Annual peak electrici~ demand (kW, entre building ).. . . . . . . . . . . . . . .,, . , 3.5

Escalatmn of conventmnal ● nergy costs ——

Constant reel Energy price Energy price

energy price} escalation 1 escabatlon II

1 1976 Startup

a. Costs ullng solar (conservation) system.

Total with no tncentwes . 137 (177 )

Total with 200/0 ITC ...,.:.

153. (193 ) 198

129

(238.)

(170 ) 145 (186.] 190

Total w!th full mcentlves 110

(231.)

(147 ) 126. (163.) 171 (208.)

b. Costs using conventional reference system 122 164.

2 1985 Stortupd

233.

a. C0st5 using solar (conservation) system.

(capitol related costs). . 87. [128.) B7. (128.) 87 (128.)

(operation & mcuntenonce costs). . 3 (3 ) 3 (3 ) 3. [3.)

(fuel bill ) 9 (9)

(electrtc bill )

19. (19.) 28

37.

(28.)

(37.) 53 (53.) 114. (114 )

Total with no incenfwes . . . . . . . . . . . . . . . . . . . . . . . . 137 [177 ) lbl. [202.) 232 [272 )

Total with 20% IT..,......, . . . . . . . . . . . . . . . . . 129 (170.) 153. (195.) 224 (265 )

Totol with full incentwes . . . . . . . . . . . . . . . ., 110 (147 ) 135. (172 ) 205 [242.]

b Costs using conventional reference system . . . . . . . . 122 187 295.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system IS SF-7)

—

Type of Incentwes given

Levelized cost of solar energy No Full

or ‘consewotion’ energy’ incenhves 20% ITC incentwes

$/ MMBtu primary fue l 361 (6 36) 3.05 [5.B8) 1.79

@fkWh electnci~ 4.24

(4.30)

[7 48) 3.59 [6.93) 210 [5.06)

Escalation of conventional energy costs

Constant real Energy price Energy price

Levelizedpr!ce paid for conventional energ~ e energy prices escalation I escalation II

$’MM6fu prlmory fuel... . . . . . . . 3.25 4.87 7.51

t kWh electrici~... . . . . 3 8 2 5.73 8 8 4
———-———-

//f’f /1//////

c1

Table IV.16.—Albuquerque: Conventional System— Insulated Single Family House With Gas Heat, Hot Water,

and Gas-Powered Absorption NC (IF-7)

~u?l L,ne

r

, “ T;

< t ,, ,, M ISC

~

----- f-------, , ~ ‘

,.-

Gr,d \

\

Electric , / ” ‘ \ ,

E ~~! , ‘, Electr+cIIy Loads ‘K<, e

.\ 1,!, , “-”-+> J ––.—.––––=:==:–->

A :1 , -j~;’-~’ =“;~; yg ,~1 ~ ——

t<t <. E x P J ], ,

1- 1 R-----

Gas

? {

.;=~l

r

Absorpllon

—.

T rt, ,,,-

1

I

chiller Heallng

//,VL

J

~.::......-l=:::.l z=..r==’=:’g, ,

I

&

k

~– ---; .<! ,.(-.---- l I

IL

~’

—––––––—..——––—

Coollng

Load s

%%..: , :,, J j_ ‘---- 1, m ““-’–’

m-’ “

;

Gas

I

Furnace

I

I

I --’-=:$:FFJ::F “r “’’’’change ’

‘ L

?

Gas Ho!

-1 ,_

L

~-. — -’

Water --- * Hot Water

‘. .3 >

supply

-— s

* Water Loads \. ./’ -

- ‘

- Gas Absorption

Heater

--7 -— Alr Condl[lonlng

A. ITEMIZED COST OF COMPONENTS B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b

’

c

(Conventional reference system is IF-71

Unit First cost

Component

Annual Life

Size cost (incl. O&P) O&M (yrd

1. Go* Iumoce . . . . ““ 31 MBtuh 15 $/MBtuh $465 0 15

2. Ductwork . . . . . . . . — 425 0 30

3. Central absorption of c

—

., . . 1,3 tons 850 $/ton 1,100 $20 15

4. Go% water heater .. .,.,.. . . . . . . . . . 40 gal. 225 ea. 225 0 15

5 Extra inwlation, !tor~ doors and windows.. . . . . . . . . . . . . . . . — — 981 0 30

TOTAL FOR BUl~DING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . S3,196 S20 TOTAL PER UNIT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $3,196 S20

ANNUAL ENERGY FLOWS (Conventional reference SyStern is IF-7)

Energy consumed Backup consumed W/ Energy $CWWJ

by ref. system sOlar/cOnnwatiOn (% of total)

Net Electricity (bought+old] (MWh/unit)..... . . . . . . . . . . . . . . 7.8 7.8 0

Fuel consumed on~ite (MMBtu/unit).........,...,............ 169. 169. 0.

Total energy requwement (bbl crude equiv.~ . . . . . . . . . . . . 54. 54. 0.

Electricity sold to grid Onnually (MWh,entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o.

Annual ~k electricity

.———

demand (kW, entire building).. . . . . . . . . . . . 3.4

Escalation of conventional energy costs

Ccmtont red Energy price Energy price

energy prices escalation I escalation II

1. 1976 Startup

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 110. (126.) 145. (161.) 206. (222.)

Total with 207. IT.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 110. (126.) 145. [161.) 206. [222.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 110. (126.] 145. (161.) 206. (222.)

2. 1985 startup~

(copital reloted costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 34. (49.) 34. (49.) 34, (49.}

[operation & mointencmce colts) . . . . . . . . . . . . . . . . . . . . . . . 3. (3.) 3. (3.) 3. 13.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37. [37.] 75. (75.) 111. [11 1.)

(efectric billJ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37. [37.) 52. (52.) 112. (1 12.]

Total with no incentwes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 110. [126.) 163. [179.) 264). (276.)

Total with 207. ITC . . . . . . . . . . . . . . . . . . . . . . . . . . . 110. (126.) 163. (179.) 260. [276.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 110. (126.) 163. (179.) 260. (276.)

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference ~ystem is IF-~

Type of incentives given

Levelized cost of solar energy No Full

or ‘conservatism’ emerg~ incentives 20% ITC incentive

$/MMBti primary fuel............,..................,...... N / A [F4/A) N / A [N/A) N / A (N/ ~

@/kWh e&tiici~....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . N / A (N/A) N / A [N/A) N / A (N/A]

—

Escalation of conventional energy costs

Constant real

—

Energy price Energy price

Levelizeci#ce poid for conventional energ# t energy prices escalation I escalation II

$/AfM8tu p“n?ary fowl. . . . . . . . . . . . .. 3.37 4.97 779 —

a/k Wh ebctricity..... . . . . . . ~ 3.96 5.84 9.17

—
Table IV-1 7.-Albuquerque: Solar Heat Engine Cogeneration System— Insulated Single Family House Using ORCS With Cooling Tower,

One-Axis Tracking Collector (Possible Future Design), Low. Temperature Thermal Storage; Building Equipped With IF-7 Space-Conditioning

;------------- , , +--1:.

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I I

ITEMIZED COST OF COMPONENTS

Unit First cost Annual Life

Component Size cost [inCl. O&P) 06M (yrs.)

1 1 -axis E-W tracking collector.... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 46 m’ 129 $/m’

{

. $2,970 0 3 0

2,970 0 15

——Collector @ 80 $/m’

——lnstollatlon @ 20 $/m’

——Sh!pping @ 3 $/m’

—.--overheod ond profit @ 25%

2 Hot water storag e . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 200 kWh 2 $/kWh 41Xl o 30

3. Fossil boder—cast iron.. . . . . . . . . . . . . . . . . . . . 21.7 47 $/kW 1,000 0 15

4 Absorption a/c. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.3 tons 850 $/ton 1,100 $20 10

5. Woter-to-arr heot exchanger . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9 10 $/ton 90 0 15

6 Insulated steel pipe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125 ft 4.1 $/ft 513 0 30

7. tieot ● xchanger, pumps ond controls., . . . . . . . . . . . . . . . . . . . . . . . . . — — o 10

8. Ductwork . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 425 0 30

9 Extra mmdotion, storm doors and windows......,........,,.... — — 981 0 30

10. Orgon,c turbine (in~talled with coohng tower, controls, 4.3 kW 490$/kW 2,110 30 15

and high temperature heat exchanger, and generator).

TOTAL..,. . . . . . . . . . . . . . . . . . . . . . . . . . . . . $13<059,0c30 $50

“ ‘, installed collector cost assumed replaced m t 5 yrs with total replacement !n .30 yrs

ANNUAL ENERGY FLOWS (Conventional reference system is IF-7)

Energy consumed 8ockup conwmad w/ Energy saved

by ref. system dzr/cOnsarvOtiOn (% of total]

Net Electricity (bought-sold) (MWh/unit). . . . . . . . . . . . . . . . . . . 7.8 0. 100.0

Fuel consumad cmsite (MMBtu/unit). . . . . . . . . . . . . . . . . . . . . . . . . 169. 151. 10.8

Total energy requirement (bbl crude equiv.~ . 54. 31. 42.2

Electricity sold to g,id annually (MWh,entire building) ..., . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Annual peak electricity demand (kW, entwe building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

0.

0.

@

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-,. ---

. . Absorpoon

Chiller

Orgamc Turbine

Eng!ne

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars) b’

c

(Conventional reference system is IF-7)

Escalation of conventional energy costs

Constant real Energy price Energy price

energy prices escalation I escalation II

1. 1976 Startup

a. Costs uxing sokar (conservation) system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 184. (249.) 206. (271.) 226. (291.)

Total with 20% ITC........................,.,.......... 168. (236.) 191. (258.) 211. (278.)

Totol with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 134. (192.) 156. (215.) 177. (235.)

b. Costs using conventional reference system . . . . . . . . I 10. 145. 206.

2. 1985 Stmtq#

0. Costs using solar (conservation) system:

(capital related casts.................................,.... 1 4 . (209.) 144. (209.) 144. (209.)

[operation & maintenance costs] . . . . . . . . . . . . . . . . . . . . . . 7. (7,) 7. (7.) (7.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33. (33.) 67. (67.) ;: (w.)

(electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o. (o.) (o.] o. (0.]

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 184. (249.) 21:: [283.) 250. [315.)

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 168. (236.) 203. (270.) 235. (302.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 134. [192.] 168. (227.) 200. [259.)

b. Costs usihg conventional reference system . . . . . . . . 110. 163. 2150.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system IS IF-7)

Type of incentives given

Levelizecl cost of solar enargy No Full

or “conservation” energfl incentives 20% ITC incentives

$/MM6tu prima~ fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12.46 (19.53) 10.80 (18.1 1) 7.02 [13.39)

$/kWh electrici~..... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14.66 (22.99) 12.71 (21.32) 8.27 (15.76)

Escalation of conventioncd energy costs

Constant raal Energy price Energy price

Levelizedprice paid for conventional enetg~’ energy prices escalation I escalation II

$/ht MBhI primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.37 4.97 7.79

4/k Wh ektiici~....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.96 5.84 9.17
Table IV-1 8.—Albuquerque: Solar Heat Engine Cogeneration System— Insulated Single Family House Using ORCS With Cooling Tower,

One-Axis Tracking Collector (Possible Future Design), High-Temperature Thermal Storage, Gas Backup;

————.

Building Equipped With IF-7 Space-Conditioning

—- ,

1

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i

L–m‘-::--’---------------------:-=-+54 A. ITEMIZED COST OF COMPONENTS

Unit First cost

Component

Annual Life

S,ze cost (incl O&P) O&M (y IS)

1. One axis E–W trocklmg collector 46 m’ 129 $/m’ .$,2970 0 30

——Collector @ 80 S ml

. 297 0 0 15

——ln$tollotion @ 20$ mz

—Shipping @ 3$/c-nz

——-overhead and profit 25”/.

2 High temperature oil stomge.. . . . . . . . . . . . . . . . . . . . . . . 80 kWh 19 $/kWh 1,520 0 30

3. Fossil bailer-cast mom . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21.7 kW 47 $/kW 1,000 0 15

4 Absorption a/c . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.4 tons 850 $/ton l,20i3 S20 10

5 Woter-to-air heat exchange, . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9 kW 10 $/kW 90 0 15

6. Imulated !teel pipe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125 ft 4.1 $/ft 513 0 30

7 Heat exchanger, pUnIp, and ~onVols,,.. . . . . . . . . . . . . . . . . . . . . . . . . . . — — o 10

8, Ductwork . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 425 0 30

9. Extra Inwlation, itor~dmr$ and ~i”dows . . . . . . . . . . . . — — 981 0 30

10. Orgamc turbine (Instqlled with coaling tower, controls 4.3 kW 490 $/kW 2,110 30 15

ond high temp heat .aXchonger, and generatOr.

TOTAL FOR BUILDING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $14,279 $50

TOTAL PER UNIT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $14,279 $50

-—

. 1, Installed L~lle~fOr cOst assumed replaced I!~ 1‘I )r~ Wlfh IuLII rPDlacemenf n dU yrs

ANNUAL ENERGY FLOWS (Conventional reference System is IF-7)

Energy consumed Backup consumed w/ Energy saved

by ref. system 5alar/ccms8wati0n ( % of total)

Net Electricity (baught-dd) (MWh/unit).. . . . . . . . . . . . . . . . . . 7.8 1CX3.O

Fuel ccmzumed onsite @tMBtu/unit)........................,. 169. 8:: 50.3

Total energy requirement (bkd crude equiv.~ . . . . . . . . . . . . 54. 17. 67.8

Ekctricity said to grid annually [MWh,entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Annual peak electricity demand (kW, entire buildiW)...........,.....,,, ,,, ., . . . . . . . . . . . . . . . . . . . . . . . . . . . . ::

—.

~fcmdgp

~

‘, . . 1. ,’

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,., . ,.r L,. .

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B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b,

c

(Conventional reference system IS IF-7)

Escalation of conventional energy costs

Constant real Energy price Energy price

energy pricef escalation I escalation II

1. 1976 Stortup

o. Costs using salar [conserwtian) system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 183. (255.) 196. (268.) 207. (279.)

Total with 20% IT.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 166. [240.) )78. (253.) 189. (264.)

Totccl with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . 125. (189.) 138. (202.) 149. (213.)

b. Costs using conventional reference system . . . . . . . . 110. 14.5. Zod.

2. 1985 Startupd

0. Costs using solar (conservation) system:

(capital related costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 158. (230.) 158. (230.) 158. (230.)

[aperation i% maintenance costs) . . . . . . . . . . . . . . . . . . . . . . . 7. P.) (7.) (7.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18. [18.) 3;: (37.) 5:: (55.)

[electric billl . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o. [0.) o. (0.) o. (0.)

Total with na incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 183. (255.) 203. (275.] 221. (292.)

Total with 2070 IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 166. (240.) 185. (259.) 203. (277.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125. [189.) IU. (209.) 162. (227.)

b. Costs using conventional reference system . . . . . . . . ? Jo. Id.?. 2CS0.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Canventioncd reference system is IF-7)

—

Type of incentive given

Levelized cost of salar energy No Full

or “conservation’ energ~ incentives 20% ITC mcentwes

$/MMBtcJ primary fuel.................,...........,........ 8.72 [13.58) 7.51 [12.55) 4.77 (9 12)

U/kWh ek*iciw... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10.26 [15.99) 8.84 (14.77] 562 (10.74)

Escalatmn of conventional energy costs —

Canstcmt real Energy prnce Energy prfce

Levelizedprke paid for conventional energ~ ‘ energy prlcet escalation I escalation II

$/MMBtu primary fuel. . . . . . . . . 3:37 497 7.79

e/k Wh ehsctrici~. 3 9 6 5 8 4 9. ?7
Table lV-19.—Albuquerque: Solar Heat Engine Cogeneration System— Insulated Single Family House Using ORCS With Cooling Tower,

One-Axis, Tracking Collector (Possible Future Design), Battery Electrical and High”Temperature Thermal Storage, Gas Backup;

Building Equipped With IF.7 Space-Conditioning

~

I%nw S!cna.Ja 7

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A. ITEMIZED COST OF COMPONENTS B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b

’

c

(Conventional reference system is IF-7)

Escokation of conventional ● nergy costs

Unit Flr\t co,t Annual Life

Component Size cost (incl. O&P) O&M (yrs)

1. One axis E-W tracking collector . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ——Collector @ 80 $/m’

——installation @ 20 $/mz

——Shipping @ 3 $/m*

——Ovesfsead and profit = 25%

2. High temperature oil storage . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

3. Fossil boiler-cast iron . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

4, Absorption A/C.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

5. Water-to-air heat exchanger . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

6. Insulated tteel pipe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7. Heat exchanger, pumps, and controls . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

8. DuCtio&........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9. Extra insulation, storm doors and windows . . . . . . . . . . . . . . . . . . . . .

10. Organic turbine (installed with cooling tower, controls,

and high temp. heat exchcmger und generator.

11. Battery and space . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

12. Power conditioner . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

46 ml129 $/m’ .$2,970

. 2.970

0 30

0 15 Constant real Energy price Energy price

energy prices escolotion I escalation II

1. 1976 startup

0. Costs using solar (conservation) system:

Total with N incentive$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20°4 ITC.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . b. Costs using conventional reference system . . . . . . . .

2. 1985 Stortupd

a. Costs umng solor [conservation) system:

(capital related casts . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

{operotion & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . .

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20% ITC..... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Cosh using conventional reference system . . . . . . . .

100 kWh

21.7 kw

1.4 tons

9 kW

125 ft.

—

—

17 $/kWh

47 $/kW

850 $/ton

10 $/kW

4.1 $/ft.

—

1,700

l,m

1,200

5;

500

425

981

2,110

0 30

0 15

20 10

0 15

0 30

0 10

0 30

0 30

30 15

207. (287.)

187. (270.)

141. (212.)

r 10.

221. (301.)

201. (284.)

155. (226.)

145.

234. (314.)

214. (297 )

168. (239.)

20d.

177. (257.)

9. [9.)

21. (21.)

o. (0.)

207. (287.)

187. (270.)

141. (212.]

110.

177. (257.]

9. 19.)

177. (257.)

9. (9.)

62. (62.)

o. (o.)

249. (329.]

229. (312.)

183. (254.)

2do.

— — 4.3 kW

— 490 $/kW 42. (i2.j

o. (o.)

229. (309.)

209. (291.)

10 kWh

5 Kw

78 $/kWh

124 $/kW

780 6 10

580 6 30

163. [234.)

Id.?. TOTAL FOR BUILDING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $15,819 $62

TOTAL PER UNIT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $15,819 $62

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system is IF-7)

. ‘ I ms!alled collector cost assumed replaced In 15 yrs wth total replacement In 30 Yrs Type of incentives given

Levelized cost of solar energy No Full

ANNUAL ENERGY FLOWS or ‘conservation’ energ~ incentives 20% ITC incentives (Conventional reference system is IF-7)

Energy CCWWIWd Backup conwmwd w/ Energy saved

by ref. \ystem sOlcw/cOnsewatlOn [“/. of total)

$/MMBtu primaty fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . 10.83 (16.59) 9.37 (15.34) 6.04 (1 1.18)

C/kWh el~tiici~...... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12.75 (19.52) 11.02 [18.05) 7.11 [13,16)

E~colation of conventional energy costs

Constant real Energy price Energy price

Levelkwlprice pmd for conventional energfle energy price! escolcction I escalation II

$/hfhfBtu primary fuel..................,...............,... 3.37 4.97 Z79

VkWh electricity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.96 5.84 9.17

Net Electricity (bought-sold] [MWh/unit).... . . . . . . . . . . . . . . . 7.8 0. 100,0

Fuel consumed onsite (MMBtu/unit).. . . . . . . . . . . . . . . . . . . . . . . . . 169. 95. 43.9

Total energy requirement [bbl cru& equiv.p . . . 54. 20. 63.7

Electricity sold to grid onnwlly (MWh,entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.

Annual peak electricity &mcmd (kW, entire &iMiW)......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.
Table lV-20.—Albuquerque: Conventional Heat Engine Cogeneration System— Insulated Single Family House Using Stirling Engine

(Low Efficiency) Direct-Drive Heat pump, Gas Hot Water; Building Equipped With IF-9 Space”Conditioning

-++W-h+

IL

I

I

I

I

I

I

I

I

I

I

I

I

I

I

I

I

I

L- r–––. .

L,!f=J ) t) I

1 I

A. ITEMIZED COST OF COMPONENTS

—

1.

2

3

4

5.

6

7.

8

Unit First cost

Component

Annual Life

Size cost (inCl. O&P) O&M (yra)

Heat Pump. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.30 tons 800 $/ton $1,040 $50 10

Ductwork . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 425 0 30

Low temperature hot water storogo...........,, . . . . . . . . . . . . . . . . . . . . . 50 kWh 2 $/kW o 30

Fossil water heater . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 gal 225 eo. ;E o 15

Stirling engine (q = 0.32].......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7.2 kW 188 $/kW 1,3s0 100 10

——Eng!na (less generotor) @ 150 $/kW

——Overhead and profit @ 25%

Generator . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.5 kW 37 $/kW 204 0 10

Heat exchanger... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — 33$ ea. 33 0 30

Extra msulat!on, storm doors and windows . . . . . . . . . . . . . . . . . . . . . . . — — 981 0 30

TOTA1. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $4,358 $150

—

ANNUAL ENERGY FLOWS (Conventional reference System is IF-7)

Energy consumed Backup consumed w/ Energy saved

by ref. system sOlar/consewotiOn (% of total)

Net Electricity (bought-sold) (MWh/unit)..... . . . . . . . . . . . . . . 7.8 0. 100.0 —

Fuel com.mwck orisite (MMBtu/unit)... . . . . . . . . . . . . . . . . . . . . . . . 169. 142. 16.1

Totol enera~ requirement bbl crucka muiv.p . . . . . . . . . . . . 54. 30. 45.6

Electricity sold to grid arwwaffy (MWh,entire kiMi~)......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.

Annual peak electicifY ~~~ IkW, entire buildimg) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.

I), \~ ‘ Outsde

} Heat Exct Bat Pump ~———/ — -.

Stlrllng

Heat Engine

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Doksrs)b.c

(Conventional reference *ystem ii IF-7)

Iangel

Escalation of conventioncd energy costs

Constant real Emergy price Energy price

energy prices escolaticm I e3c01ati0n II

1. 1976 Stortup

a. Costs using $OIOr (ccmservotion) system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 113. (137.) 135. (158.) 154. (177.)

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 111, (136.) 133. (157.) 152. (176.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 107. (130.) 128. (151.) 147. [171.)

b. Costs using conventional mfemnce system . . . . . . . . 110. 145. 206

2. 1985 stortup~

a. Costs using mlar (ccmsewotion) system:

(capital related costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 64. [84.) 60. [84.] 60. (84.)

(operation & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . . 22. (22.) 22. (22.) 22. (22.)

[fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31. (31.) 63. (63.) 93. [93.)

[electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o. (0.) o. (0.) o. (o.)

Total wItfI no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 113. (137.) 146. (170.) 176. (200.]

Total with 20”A ITC...,...............................,...... 111. (136.) 144. (168.) 174. (198.)

Total with full lncen!wes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 107. (130.) 140. (163.) 170. (193.)

b. Costs using conventional mfemnce system . . . . . . . . 110. 163. 260.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system if IF-7J

Type of incentives given

Levelized cost of $olar energy No Full

or ‘conservation’ energ# incentives 20% ITC incentives

$/MMBtu primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.63 [7.04) 4.45 (6.88) 4.02 (6.34)

$/kWh ektiici~....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.45 (8.28) 5.23 (8 09) 4.73 [7 46)

Escalation of conventional energy costs —

COnstOnt real Energy price Energy price

[e.elizedpnke paid for conventional energ~ ‘ energy prices escolatlon I escalation II

S/AtMBtu PCImry fowl. . . . . . . . . . . . . . . . . .. ‘— — 3 3 7

———

4.9 7 7.79

~/kWh ekdricify.... . . . . . . . . . . . . . . . . 3 9 6 5 8 4 9.17

- -
Table IV-21 .—Albuquerque: Conventional System— All Electric Single Family House Using Heat Pump Heating (SF-2)

r t \

+t+++H+ “ ‘“” “

c l

- .: .Wpi--J-‘ ::;5 :

- 

Loac w ,

A. ITEMIZED COST OF COMPONENTS

Unit First cost

Component

Annual Life

Size cost (incl. O&P) 06M (yrs)

1. Heat pump . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 tom 800 $/ton $1,480 $50 10

2. Duc~o&.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 425 0 30

3. Electric water heater . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 gal 225 ea. 225 0 15

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $2,130 $50

ANNUAL ENERGY FLOWS (Conventional reference system is SF-2)

Energy consumed Backup consumed w/ Energy saved

by ref. system scJOr/cOnwwcctmn (“/. of total)

Net E~~ici~ [baught-~) [MWh/unit)..... . . . . . . . . . . . . . . 32.5 32.5 0.

Fuel consumed onsite (MMBtu/unit). . . . . . . . . . . . . . . . . . . . . . . . . . o. 0. 0.

Total energy requirement (bbl crude ~ui..p . 79. 79. 0.

Electricity Ad to gtid annually (MWh,entire bumming).. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.

Annual peak electricity demand (kW, entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25.6

-’=-..==

>

—

----

4-----J

Outsde

Heat Exchanger

-.

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b’

c

[Conventional reference system if SF-2)

Escolotkn of conventional energy cotts

Constant red Energy price Energy price

energy prices escalation I escalation II

1. 1976 Startup

Total with no incentive! . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 156. (169.) 186. [199.) 310. [322.)

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 156. (169.) 186. (lW.) 310. [322.)

Total with full mcentwes . . . . . . . . . . . . . . . . . . 156. (169.) 186. (lW.) 310. (322.)

2. 1985 Startupd

(capitol related costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32. [44.) 32. (44.) 32. (44.]

(operation 4 maintenance ca~tx) . . . . . . . . . . . . . . . . . . . . . 7. (7.) 7. (7.] 7 (7.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0. (o.) o. (o.) o. (0.)

lelectrtc bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 117. [1 17.) 164. (164.) 355. (355.)

Total with na incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 156. (169.) 203. (216.) 395. (407.)

Tatal with 20% IT.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 156. (169.) 203. (216.) 395. (407.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 156. (169.) 203. [216.) 395. (407.]

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference ~ystem is SF-2)

Type of incenhves given

Levehzed co!t of solar energy Na Full

or ‘conservation’ ener# incentives 20% ITC incentives

$/MMBtu primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . N / A (N/A) N / A (N/A) N / A [N/A)

$/kWh ehtiici~....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . N / A (N/A) N / A (N/A) N / A [N/A)

E~calation af conventional energy costs

Canstont real Energy pr(ce Energy price

levelizedprice pwd for conventional energ#’e energy prices escalation I escolcctian II

$/MMBhI primary fuel..................................,... 3.66 4.61 8.47

~/k Wh ekhri~......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.31 5.42 9.97

●

3-.
Table lV.22.—Albuquerque: Conventional System –All Electric Single Family House Using Improved Heat Pump Heating (High Price) (SF-2)

EIIl---

c1

.,

,.

. . . !

.,. , , . .

-.

F=l-_

A. ITEMIZED COST OF COMPONENTS B. LEVELIZED

UnlI First cott Annuol Lif e

Component Size Co$t (incl. O&P) O&M (yrs)

1. Heat mm.....,.. . . . . 1.85 tons 1,440 $Ifon $2,660 $50 10

— Compressor

II

I

0’

I

Ou[slde

Hea[ Exchanqer

MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b’

c

[Conventional reference system is SF-2)

Escalation of conventional energy costs

COn*tant real Energy price Energy price

energy prices escalation I escalation II

2. Duct+it’. . . . . . . . . . . . . . . . . . . . . . — — 425 0 30

3. Electric water heater ..,,... 40 gal 225 W. 225 0 15 1. 1976 Startup

a. Costs using solar (conservation) system:

TOTAL., . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $3,310 $50 Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Toted with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b Cosh using conventicmd reference syskm. . . . . . . .

2. 1985 Startupd

0. Costs using solar (Con$ewotion) system:

(capital related coats . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

(operation & maintenance coats) . . . . . . . . . . . . . . . . . . . . . . .

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . [electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Totol with M incentwe~ . . . . . . . . . . . . . . . . . . .

Total with 20% IT.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total wth full incentives . . . . . . . . . . . . . . . .

b Costc using conventmnol reference system....,...

162. (181.)

160. (180.]

155. (174.)

?s6.

188. (208.)

186. [206.]

182. (201.]

186.

295. [315.)

293. (313.)

289. [308.)

3?0.

53. p3.) 53. (73.) 53. [73.)

(7.) (7.) 7. (7.j

:: (0.) ;: (0.) (0.)

101. (101.) 142. [142.) 32: (309.)

162. [181.) 203. (222.) 369. (389.) 160. [180.)

155. [174.)

156.

201. [221.)

196. (215.)

203.

367. (387.)

363. (382.)

395.

—.—.—

ANNUAL ENERGY FLOWS (Conventional reference system is SF-21

.— -

Energy consumed Backup consumed w/ Energy saved

by ref. system solOr/conwwvatiOn (“/ 0 of total)

Net Electricity (bought-sold) (Mwh/UnitL.. . . . . . . . . . . . . . . . . 32.5 27.8 14.5

Fuel conwnwd on$ite (MM8tu/unit). . . . . . . . . . . . . . . . . . . . . . . . . . o. 0. 0.

Totol energy requirement (bbl crude equw.p . . . . . . . . . . . . 79. 68. 14.5

Electrlcl~ sold to grid annually (MWh,entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.

Annual peak electricity de~nd IkW, entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25.6

.— —

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system is SF-2)

Type of incentives given

Levelized cost of solar energy No Full

or ‘conservation’ energ~ incentives 20% ITC incentives

$/MM8tu primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.48 (8.77) 4.06 (8.42) 3.13 (7.25)

C/kWh electricity . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.27 (10.32) 478 (9 91] 369 (8.54]

Escalation of conventional energy costs

Constant real Energy price Energy price

levelixedprke paid for conventional energ~ “ energy prices ● scalation I escalation II

$/MMBtu primary fuel . . . . . . . . 3 6 6 847 -

&kWh e&ctrkify...... . . . . . . . . . . . . . . . . . . .

4.61

431 5 4 2 9 9 7

. . . . .
Table IV-23.—Albuquerque: Conventional System— All Electric Single Family House Using Improved Heat Pump Heating (Low Price) (SF-2)

B

+t+t+H+ ‘-’”” “

MISC

* Elecmc

Load

Improved

, 1

— Eleclr,c Hw

HW b Loaa

I

*

Heater

.

~ = 08 5

A. ITEMIZED COST OF COMPONENTS

Component

Unit Fir\t cost Annual Life

Size cost (incl, O&P) O&M (yrs]

1. Heot pump . . . . . . . . . . . . 1.85 tons 960 $/ton

2. DucWo&.....................................................,......... . . . . . . . . . . . —

$1,780 S50 10

— 425 0 30

3. Electric water heater . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 gal 225 ea. 225 0 15

TOTAL..,.... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . S2,430 S50

ANNUAL ENERGY FLOWS

IConventioml reference system i~ SF-2)

Energy consumed .ockup consumed w/ Energy saved

by ref. system sOlar/cOnsewatiOn (% of totol)

Net Eldricity (bought-told) (MWh/unit). . . . . . . . . . . . . . . . . . . 32.5 27.8 14.5

Fuel corwumed onsite (MMBtu/unit)................,......... o. 0.

Total energy requirement (bbl crude equiv.p. . . . . . . . . . 79. 4: 14.5

Electricity sold to grid annually [MWh,entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Annuol peak ebctncity derrmnd (kW, entire hiMiW]................................................................., . . . . . . . . . 25°;

— \ \

.—----+\

N.—r_-Y-..

Heat Pump

Compresso[

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars) b”

c

(Conventional reference system is SF-2)

Escolotion of conventional ene,gy costs

Constant real Energy price

energy prices escabticm I

1. 1976 Startup

0. Costs using solcw (conservation] system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 147. (lbO.) 173. (187.)

Totol with 20% ITC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 146. (160.] 172. (186.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 145. (159.) 172. (185.)

b. Cosh using con.enhbncd rwference system . . . . . . . . 157. 187.

2. 1985 Stortund.

a. Costs using 80br (conservation) system:

(capital related casts, . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

(opemtion & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . .

[fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Totol with 207. ITC............,.............,...............

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Costs using conventional reference system . . . . . . . .

Energy price

● scabticm It

280. (294.)

279. (293.)

279. (292.)

310.

38. (52.) 38. (52.) 38. (52.)

7. P.) 7. (7.1

o. (0.)

(7.)

o. (o.) ::

101. (101.)

(o.)

142. (142.) 309.

147.

(309.)

(16.0.) 187. (201.) 354. 146. (160.) (368.)

187. (201.) 353.

145. (159.)

(367.)

186. (200.) 353.

157.

(366.)

204. 395.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

[Conventional referenco system is SF-2)

Type Of incentives given

Levelizecl cost of wbr energy No Full

or ‘consewotion’ energ~ incentives 20% ITC incentives

$/MMBtu primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.15 (4.16) 1.04 (4.07J .90 (3.78]

C/kWh e&tici~........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.35 (4.90) 1.23 (4.s0) 1.06 [4.45)

Escobtion of conventional energy costs

Constant real EnerIJy price Energy price

Le.elizedprire paid for conventional eneW#’.* energy prices ● scakaticm I escabtion II

$/Mhi8tu P“WV fwi...................................,.. 3.66 4.61 8.47

C/kWh ekti2i~........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.31 5.42 9.97

2

z

J’

3-.

w-
Table IV-24 .—Albuaueraue: Solar Hot Water System— Single Family House Using Flat-Plate Collectors (1977 Prices);

Building Equipped With SF-2 Space-Conditioning

. .

El ,. ,. -,

I

I

r-n

L.

I --J

1

L_.

!

1

I J L-l

—

A. ITEMIZED COST OF COMPONENTS

Umt First cost Annual Life

Component Size cost (inci. O&P) 06M (yrd

1 Heat pum p . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 tons 800 $/tons $1,480 50 10

2 Ductmg . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — 425 0 30

3 Hot water ~torage with electric backup (including heat 100 gal SGs 355 0 30

exchanger).

4 Pumps and controls . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — $250 250 0 10

5 inwlated steel pipe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 75 ft $2.6/ft 195 0 30

6 Flat plate solar collWW....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 m’ 143 S/ma ● 715 15

——Collector cost @ 95 $/m* ● 71 5 : 30

——lnstallatlon @76 $/m’

——TransportOttOn @ S3/m

——Overheod and profit= 25%

TOTAL . . . . . $4,135 $50

● V2 mstolled collector cost a~sumed replaced In 15 yrs., with total replacement In 30 yrs.

ANNUAL ENERGY FLOWS

(Conventional reference system is SF-2)

Energy COtlWIWd Bockup consumed W/ Energy saved

by ref. system wJor/cOnsewOtiOn (“/. of total)

Net Electricity (bought~pld] (MWh/unit).........., . . . . . . . . 32.5 23.3 28.4

Fuel consumed onsite [AMBtu/unit).....,....,..,...,...,.... o. 0. 0.

Total energy requiremwt (bbl crude cquiv.p . . . . . . . . . . . 79. 57. 28.4

Electricity sold to grid ~nnually IMWh,entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Annual peak electricity demand [kW, entire hilding).. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 275

‘-x Y- .

-—J - - Heat Pump Sloraqe

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b:C

(Conventional reference system is SF-2)

Escalation of conventional energy cotts

Constant real Energy price Energy price

energy prices cscakation I escalation II

1. 1976 Startup

a. Costs using solar (conservation) system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 147. [169.) 170. (191.) 26J. (283.)

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . IU. (166.) 167. (188.) 258. (280.) Total with full incentive$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 140. (157.) 162. (179.) 254. (271.) 6. C05fc usihg convenfkwnal reference system . . . . . . . . 15Z 18Z 310.

2. 1985 Startupa

0. Costs using solar (consewotion) system:

(capital reloted costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 53. (74.) 53. (74.) 53. (74.)

[ofnwation & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . . 7. (7.) (7.) (7,)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o. (o.) ;: (o.) :: (0.)

[electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 87. (87.) 122. [122.) 2U. [264.)

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 147. (169.) 182. (204.) 325. (346.)

Total with 20”/. IT....................., . . . . . . . . . . . . . . . . 144. (166.) 179. (201.) 322. [343.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 140. [157.) 175. (192.) 317. (334.)

b. Costs using corwenttonal mfemnce system . . . . . . . . 75Z 204. 39.5.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

[Conventional reference $ystem is SF-2)

Type of incentive given

Levelized cost of solar en.rgy No Full

or ‘consewation’ ● nergy’ incentives 20% ITC incentive!

$/MMBtu primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.30 (4.65) 1.94 (4.34) 1.47 (3 33)

$/kWh eltitiici~.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.70 (5.471 2.28 [5.1 1) 1,73 (3.92)

E~ccdation of conventmnal energy costs

Constant real Energy price Energy price

[evelizedprike paid for conventional ener#’e energy prices escalation I escalation II

$/MAfLW P“MWY fuel. . . . . . . . . . . . . . . . . . . . . . . . 3.66 461 8.47

t/k Wh ebctric,ty. . . . . . . . . . . . . . . . . . . . . 4.31 5.42 9.97
Table IV.25.—Albuquerque: Solar Hot Water and Heating System—Single family House Using Flat-Plate Collectors (1977 Prices),

Low-Temperature Thermal Storage; Building Equipped With SF.2 Space-Conditioning

+tw++t+ ‘

.“. —z=zzziz - m. . . .

. , . , , . 3

,,

-Ezl I ‘----

1

A. ITEMIZED COST OF COMPONENTS

Unit

Component

~i;;;t ;09, Agnu;l ~;~,

Size cost

1. Heat pump . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

2. Ductwork . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3. Collectors and associated co~ts . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

——Collectors @ 95 $/m’

——lnstollation @ 16 $/m’

——Transportation @ 3 $/m’

—25% ovethead and profit

4. Y~” insulated ~teel pipe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5. Storage (without plumbing) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

6. Pump, controls, and heat exchanger........, . . . . . . . . . . . . . . . . . . . .

1.85 tons 800 $/ton S1,480 $50 10

— — 425 0 30

25 m’ 143 $/mZ

● ),787 o 15

● 1,787 o 30

—125 ft $;1 5i ; G

200 kWh $2.05/kwh 410 0 30

— $650 650 0 10

TOTAL......,,......, . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $7,052 $50

● ?4 installed collector cost assumed replaced in 15 yrs., with total replacement in 30 yrs.

ANNUAL ENERGY FLOWS

(Conventional reference system is SF-21

Energy conwmed Backup conmcmed w/ Energy saved

by ref. system sOlar/cOnsewatiOn (% of total]

Net Electricity (bought-sold) (MWh/unit).. . . . . . . . . . . . . . . . . . 32.5 20.5 37.0

Fuel consumed ontite (MM8tu/unit)... . . . . . . . . . . . . . . . . . . . . . . . 0. 0.

Total energy requirement (bbl crude equiv.r . . . . . . . . . . . . 79. 50. 37:

Electricity sold to grid annually (MWh,entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o.

Annual peak electricity demand (kW, entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25.6

\

I — ,,

‘ -J-----J

-\ &

A

.b Outside

! . Condenser

\ ’

j~

Unl!

. . ,

Hot Water

Heat Pump Storage

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b’c

(Conventional reference system is SF-2)

Escalation of conventional energy costs

Constont real Energy price Energy price

energy prices escalation I escalation II

1. 1976 Startup

0. Costs using solar (conmmvotion) system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 171. [206.) 191. (226.) 273.

Total with 20% ITC.........................,.......,........ 163. (199.) 183.

(308.)

(219.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

265.

152. (177.)

(301.)

172. (197.)

b. Costs using conventional reference system . . . . . . . .

254.

157.

(279.)

2. 1985 Stortupd

/87. 310.

0. Costs using solar (consemation) syttem:

(capitol related cOst~).......................,........,....... 85. (121.) 85. (121.] 85.

(operation & maintenance co~ts) . . . . . . . . . . . . . . . . . . . . . . 7. (7.)

(121.)

7. (7.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7.

0. (0.)

(7.)

o. (o.)

(electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

o.

78. [78.)

(o.)

(109.) 237.

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 171. ::%.;

[237.)

;:: (237.) 329.

Total with 20% ITC.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 163. 194.

(365.)

(230.) 321.

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 152. (177:)

(358.)

184. (208.)

b. Costs using conventkwd reference system.., . . . . .

311.

15Z

(335.)

204. 395.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

[Conventional reference fy$tem is SF-2)

Type of incentives given

Levelized cost of solor energy No Full

or ‘conservation’ energfi incentive 20% ITC incentives

$/MMBtu primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.49 (7.48) 3.82 (6.91) 2.94

C/kWh el~tiici~... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.29 (8.81)

[5.01)

4.50 (8.13) 3.46 (5.89)

Escolotion of conventional energy costs

COn\tOnt real Energy price Energy price

levelizedp;ice paid for con.entionol energ~e energy prices escalation I escalation II

$/MMBhI primary hi... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.66 4.61 8.47

~/k Wh ektiici~.... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.31 5.42 9.97
Table IV-26.—Albuquerque: Solar Hot Water and Heating System— Single Family House Using Flat-Plate Collectors (1977 Prices);

Building Equipped With SF-2 Space-Conditioning

/7 —.-

‘-’”- “ “

I

-kT

~-

..,. 1 -

--1 -.----=====<” .— C=–1

—-

,,,

J1 t-k Outsde) ‘ Condenser

-1

!%s -g-w ‘n” (-+~~----..”-_r Hot Water

.f Storage

- - . . - -

Heat Pump

F--r +

.,, l---n.,, -. ,. .

Commessor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)bc

(Conventional reference system is SF-2)

A. ITEMIZED COST OF COMPONENTS

Unit First cost Annual Life

Compcment Size Coit (incl. O&P) O&M (yrs)

1 Heat pump . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 tons 800 $/ton $1,480 $50 10

2 Ductwork . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 425 0 30

3 Collectors and associated costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30 m’ 143 $/m’ .2145 0 30

——Collector! @ 95 $/m’ “ 2 145 0 15

——lnstollatlon @ 16 $/m’

——Transportation @ 3 $/m’

——25”4 overhead ond profit

4. 1. Insulated steel pipe . . . . . . . . . . . . . . . . . . . . . 125 ft 4.1 $/ft 513 0 30

5 Storage (w}thout plumbing) . . . . . . . . . . . . . . . . . . . . . . . . . 200 kwh 205 $/kWh 410 0 30

6 Pumps, controls, and heat exchanger — 650 650 0 10

Escalation of conventional energy costs

Constont real Energy price Energy price

energy prices escalation I escalation II

1. 1976 Stortup

a. Costs using solar (conservation) system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 172. (212.) 191. (231.) 268. (308.)

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 163. (204.) 182. (223.) 259. (300.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 143. (179.] 162. (197.) 239. (275.)

b. Cosh using convenPiond mfemnce system . . . . . . . . 156. 186. 310.

2. 1985 Startupd

0. Cotts using solor (consewation) syttem:

(capital related costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 92. (132.) 92. [132.) 92. (132.)

(operation & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . . 7. (7.) 7. [7.) 7. (7.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o. [0.) o. (o.) o. [0.)

[electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 73. [73.) 103. (103.) 222. (222.)

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 172. (212.) 202. (241.) 322. (361.)

Total with 20% ITC.... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 163. [204.) 193. (234.) 313. (354.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 143. (179.) 172. (208.) 292. (328.)

b. Costs using conventional mfemnce system . . . . . . . . !56. 203. 395.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system i! SF.2)

Type of incentives given

Levelized cost of solar ene,gy

or ‘consewation’ energyc

No Full ANNUAL ENERGY FLOWS incentives 20% ITC Incentwes

(Conventional reference system IS SF-2) $/MMBtu primary fuel.............., . . . . . . . . . . . . . . . . . . . . . . . 4.52 (7.53) 3.83 (6.94) 2.27 (4 99)

~/kWh electricity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.32 (8.86) 4.51 (8.17) 268 [5.88) Energy consumed Backup contumed w/ Energy $oved

by ref. wstem ~OlOr/cOn*ewatiOn (7. of total) Escalation of conventional energy cost~ —

Net Electricity (bough~.told) (MWh/unit).. . . . . . . . . . . . . . . . . . 32.5 19.0 41.4

Fuel consumed onsita (MMBtu/unit). . . . . . . . . . . . . . . . . . . . . . . . 0. 0.

Total energy requirem~nt (bbl crude equiv.)’ . . 7:: 47. 41.4

Electricity ~old to gr!d annually IMWh,entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o.

Annual peak electricity demand (kW, entire &ilding)....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25.6

Constant real Energy price Energy price

Levelizedprice pmd for conventional energ~ ● energy prices escalation I escolatlon II

$/MM8Pu primo~ fuel. . . . . . 3 6 6 461 8 4 7

ejkwh electricity... ““ 431 5 4 2 9.97
Table IV.27.—Albuquerque: Solar Hot Water and Heating System —Single Family House Using Flat”Plate Collectors (1977 Prices),

Low-Temperature Thermal Storage; Building Equipped With SF-2 Space-Conditioning

r t

I J

C2 . -, T_i

A. ITEMIZED COST OF COMPONENTS

Unit First cost Annual Life

Component Size cost (id O&p) 06M [yra)

1. Heat pump . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 toni- 800 $/ton $1,480 $50 10

2. DucWo&...................................,..........,................ . . . . . . . . . . . — 425 0 30

3. CcJbctorz ond czswcioted costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

—

45 m’ 143 $/m* ‘3,21 7 0 15

——Collector @ 95 $/m* ● 3,217 o 30

—hwtollation @ 16 $/ms

—Tronsportotion @ 3 $/mz

——25% overhead ond profit

4. Insulated steel pipe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125 ft $4.1 513 0 30

5. Storage (without plumbing) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 200 kWh $2.05/kWh 410 0 30

6. Pump, controls, and heat exchanger.....,.................,......... — $650 650 0 10

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $9,912 $50

● % installed cdlectw cost assumed replaced in 15 yrs., with total replacement in 30 yr~

ANNUAL ENERGY FLOWS

(Conventional reference system is SF-2)

Energy COIMUMed BCZCkUP c~sumed./ Energy XJV06

by ref. system sOkar/cOn~weticin (% of tOtoiJ

Net Electricity (bought-+ (MW%/unit),,........., . . . . . . . 32.5 16.8 48.4

Fuel consumed orwite (MM8tu/unit]... . . . . . . . . . . . . . . . . . . . . . . . o. 0.

Total energy requirement (bbl crude equiv.r . . . . . . . . . . . .

0.

79. 41. 48.4

Electricity dd to grid annwlty (MWh,entire buiMiW). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Annwl peak electricity demand (kW, ● ntire hiMiW). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25:

-’———f —-J -----

Heat Pump

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars) b’

c

(Conventional reference system it SF-2)

Escalation of conventional energy costs

Constant real Energy price Energy price

energy prices ezcolotti I escobtion II

1. 1976 Startup

a. Costs using solor (conservation) system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 188. (237.) 205. (254.} 274.

Totol with 20% ITC............ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 176. (226.)

(323.)

193. (243.) 262.

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 159. (191.)

(313.]

176. (208.) 245.

b. Cosh usihg conventiwml reference system . . . . . . . . 157,

(277.)

187.

2. 1985 Startupd

310.

0. Costa using zdor (conservation) system:

(capitol rebted costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 115. (164.) 115. (164.) 115.

[operation & rnointenance costs) . . . . . . . . . . . . . . . . . . . . . [7.)

(164.)

7. (7.) 7.

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . :: (o.)

(7.)

o. (0.) o.

(electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66. [66.) 92.

[0.)

(92.] 200.

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 188. (237.)

(200.)

215. (263.) 322.

Total with 20% ITC......................................,... 176. (226.)

(371.)

202. [253.) 310.

Totol with fut! incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 159. (191.)

(361.)

186. [217.) 293.

b. Cosh using conventional mkrence system . . . . . . . . 157.

[325.)

204. 395.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system is SF-2)

Type of incentives given

Levelized cost of solar energy No Full

of ‘conservoticm’ energ~ mcentivet 20% ITC i~entives

$/MM6ti Primy fad............................,........ 5.35 (8.52) 4.54 (7.82) 3.48 [5.52]

~/k#h ektici~........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.30 (10.02) 5.35 (9.21) 4.W (6. XI)

Ezcabicm of corwentionol energy cozts

Constant mol EnersIy price Energy price

Levehzedpie paid for corlvewfiorml ewW~.* energy prices escabtion I ● scobtion H

$/’MM6hI primcwy tail. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.66 4.61 8.47

~/kWh ektii~......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.31 5.42 9.97
Table IV-28.—A[buquerque: 100-percent” Solar Hot Water and Heating SyStem— Single Family House Using Flat. Plate Collectors

Community Seasonal Low. Temperature Thermal Storage; Building Equipped With SF-2 Space-Conditioning

D

k+ ,, + . .,, (

L’

Y — ——

a>

.—

— . — -. — ,.

J

I I I J!3,- 1 I

I

,. , I

A. ITEMIZED COST OF COMPONENTS

Unit First cost

Component

Annual Life

Size cost (incl. O&P) O&M (yl,.)

1. Fan coil unit . . . . . . . . . . . . . ., . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.2 kW 13 $/kW $170 0 15

2. Ductwork . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 425 0 30

3. Central dectric a/c. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 tons 430 $/ton 796 $30 10

4. Hot water tank w/heat exchange . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30 gal 225$ 225 0 15

5. Collector and as~~iated costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35ms 143 $/m’ ‘ 2500 0 15

——Collectors @ 95 $/m’ ‘ 2500 0 30

—-- Irmtallotion @ 16 $/ms

——lronsportation @ 3 $/mm’

——25”/i overhead and ~,ofit

6. Controls . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100 0 15

7. 1. inmhted steel piP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100 ft $4.1/ft 410 0 30

8. Storage . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13,000 kWh 0.5 $/kWh 6,000 0 30

9 Distribution system [including BTLJ ~ter) . . . . . . . . . . . . . . . . . . . . . . . . . — — 3,000 90 30

TOTAL FOR BUILDING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $16,126 $120

TOTAL PER UNIT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $16,126 $120

- 1, installed collector COSI a=wmed replac ed in 15 yrs w~!h !OMI repl.+cement ,n .30 ~rs

ANNUAL ENERGY FLOWS

(Conventional reference system is SF-2)

Energy consumed Backup consumed w/ Energy $CJVed

by mf. system sc4ar/cOnsewOtiOn (% of total)

Net Elec~i~ (bought, sold) (MWh/unit)..... . . . . . . . . . . . . . . 32.5 11.3 65.4

Ftml consumed onsite (&tMDtu/unit).. . . . . . . . . . . . . . . . . . . . . . . . . o. 0.

TOtal eIWWy mquirem@t (~ crude equiv.p . . . . . . . . . . . . 79. 2:: 65.4

Electricity sokd to @d WIJI~ (MWh,entire biHiW)......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Annwl -k.Iectricih -dlkW, entire buildincd . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5:

1977 Prices),

..- 1 k

-1 ———— --- - --i ‘----’

.

.

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b”

c

(Conventional reference system it SF-2)

Escalation of conventional energy cosh

Constant reel Energy prico Energy prico

energy prices exolation I escalation II

1. 1976 Startup

a. Costs using solor (comervoticm) syatem:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 216. (286.) 229. [298.) 279. (349.)

Totol with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 194. (267.) 206. (279.) 257. [329.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 164. (203.) 177. (215.) 227.

b. Costs using ccmvenfionolmfemoc

(266.)

e $ysbll. . . . . . . . ISZ 187. 310.

2. 1985 Stccrt#

a. Costs using solar (conwmvoticml system:

[capitol rebted coshl.......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 151. (220.) 151. (220.) 151. {220.)

(owrdon & rnointenance cosh) . . . . . . . . . . . . . . . . . . . . . . . 18. (18.) 18. (18.) 18. (18.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o. (0.) [0.) o. (o.)

(electric bi~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (48.] 6!; (67.) 146. (146.)

Total with I-10 incontivm . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2:: (286.) 236. [305.) 314. [384.)

Total with 20”A IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 194. (267.) 213. (286.) 292. (364.)

Totol with full incontivw . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 164. [203.) 184. (222.) 262. (301.)

b. Costs using concenfic+d dwence system . . . . . . . . 15Z 204. 395.

C EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventicmol r.ferenco system is SF-2)

Type of incentives given

Levelizod cost of tolor energy No Full

or ‘Colmervation’ enWg~ incentives 20% ITC incentives

$/MMBtcJ primoI-Y fad.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.18 [9.51) 5.10 (8.59) 3.68 (5.52)

C/kWh eWi~........... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7.27 (1 1.19) 6.00 (10.10) 4.33 (6.49)

Escolatiw! of conventional energy costi

Cormtont red Energy price Energy price

Lowfizedprice poid & conventional em_g# energy price~ escalation I escalation II

$/AfMsfufXiw fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.6d 4.6J 8.47

t/kWh Aced+-.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.31 5.42 9.97
Table IV-29.—Albuquerque: 100-Percent Solar Hot Water and Heating System— Single Family House Using Flat”Plate Collectors

(Possible Future Price), Community Seasonal Storage; Building Equipped With SF-2 Space-Conditioning

Lhc

Loads —,— --

< ; —–-

.

.(

..-. ,

Window

Afr-Condmoner

1 1 I I I water I I

Rlll I I .“[)0 y 1

L7!’. ’” /’ ///’ /

.— —— — ——/ /,

DMrlcl Heating L-EEL-I c1 Pipes

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars) b

,

c

(Canve.tional reference system is SF-2]

A. ITEMIZED COST OF COMPONENTS

Unit First cost Annual Life

Companent Size cost (incl. O&P) O&M (yrs)

1. Fan coil unit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.2 kW 13 $/kW $170 0 15

2. DucWA. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 425 0 30

3. Control electric o/c . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 tons 430 $/ton 796 $30 10

4. Hot water tank w/heat exch. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30 g. 225 $/ton 225 0 15

5. Collectors and associated costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 m’ 86 $/m2 .1 720 0 15

—Collectors @ 50 $/m’ .1 72C o 30

—Installation @ 16 $/m*

—Transportation @ 3 $/mx

—25% overhead and profit

& Cantids.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — 100 0 15

7. 1 “ insulated Oed pipd . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100 ft $4;/ft 410 0 30

8. Starage (aquifer Wfi)...... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17,CO0 kWh 0.1 $/kW 1,700 0 30

9. Distributiact piping . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 3,00il 90 30

Escalation of canventianal energy costs

Constant real Energy price Energy price

energy prices escalation I escalation II

1. 1976 Startup

a. Castt using wlar (conservation) system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Tatol with 207. it...............................,......

Total with full incentis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Costs using conventicmal mfemnce system . . . . . . . .

2. 1985 Startup d

a. Casts using sakar (conservation) system:

(capital related costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

(aperatian & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . .

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Tatal with na incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Tatol with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

178. (224.) 229. (274.)

165. [212.) 216. (263.)

148. (175.) 199. [226.)

187. 310.

166. (21 1.)

153. (200.)

136. (163.)

157.

100. (146.)

18. [18.)

o. (o.)

48. [48.)

166. (21 1.)

153. (200.)

136. (163.)

100. (146.) 100. (146.)

18. (18.) 18. [18.)

o. [0.] o. (0.)

67. (67.) 146. [146.)

185. (231.) 264. (3C9.)

172. (219.) 251. (298.)

155. (182.) 233. [261 .)

TOTAl FOR BUILDING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $10,266 $120

TOTAL PER UNIT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $10,266 $120

b. Costs using canventiancd mfemnce system . . . . . . . . 157. 204. 395 .

C. EFFECTIVE COST OF ENERGY TO CONSUMER

. ) I installed collector cost assumed re~laced m 15 yrs wfth total replacement m 30 yrs (Cacwentiaccal reference system is SF-2)

Type af incantivcs given

Levdized cost of salar energy No Full

or ‘conservation’ energ~ incentives 20% ITC incentives

$/MM8tu primary fad.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. 3.75 (5.931 3.13 (5.39) 2.30 [3.61)

U/kWh ektiici~....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.42 (6.98) 3.68 (6.35) 2.71 (4.25)

.

Escakotian af conventional energy costs

ANNUAL ENERGY FLOWS

(Canventianal reference system is SF-2)

Erwgy consumed Backup COMmWd W/ hqy ~VOd

by ref. ~ystem mlor/cansewatian (% af totol)

Net Electricity (baught+akcf) (MWh/unit). . . . . . . . . . . . . . . . . . . 32.5 11.3 65.4

Fuel cansumed atwite (MMBtu/unit]... . . . . . . . . . . . . . . . . . . . . . . . o. 0.

Total energy requirement (bbl crude equiv.)’ . . . . . . . . . . . . 79. 2:: 65.4

Electricity sold ta grid annually IMWh,entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o.

Annual peak electricity d.mand (kW, entire kiHiW)........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.2

Constant real Energy price Energy price

Levelizedmte poid fin co.ventianal erwrg#’9 energy prices escalation I escalation II

$/MM8tu ~“nqv fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.66 4.61 8.47

@/kWh ektiki~........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.31 5.42 9.97
Table IV-30. -Albuaueraue: Solar photovoltaic System— Single Family House Using Flat-Plate Air-Cooled Silicon Arrays

($0.50Matt); Building Equipped With SF-2 Space-Conditioning

. .

. .

,..

L.

—

, / .“

,. . , -

I 1

-w ‘“’

1 1 I I

I I

A. ITEMIZED COST OF COMPONENTS

Unit First cost

Component Size

Annual Life

cost (incl. O&P) O&M [yrs)

1. Heot pump. . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 tons 800 $/ton $1,480 $50 10

2. Ductwork . . . . . . . . . . . . . . . . . . . . . . . .:., . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 425 0 30

3. Electric hot water . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 gal $225 ea. 225 0 15

4. Air-cooled silicon PV (~ $/kw) [7= O. 12) . . . . . . . . . . . . . . . . . . . . . . 118 m 1 88 $/m’ “5,190 o 30

—Silicon orrcsy @ @ $/m~ “5,190 o 15

—Shipping @ 2 $/m*

——lnjtallation- @ 8 $/mz

—25% Ovedmad ~“d profit

5. Power conditioning . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6. Liohtnimg protection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

4 kW 106 1,510 15 30

— — 300 0 30

. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $14,320 $65

● % installed collector co~t as~umed rap~aced in 15 yrs., with total replacement m 30 yrs.

ANNUAL ENERGY FLOWS

(Conventional reference system it SF-2)

Energy consumed Bockup COllWWWd ./ EnewY SOVOd

by ref. system sOlOr/conwwatim (7. of total)

Net El=trici~ (bught.~) (MWh/unit), . . . . . . . . . . . . . . . . . . 32.5 4.7 85.6

Fuel consumed onsite (MMBtu/cmit).. . . . . . . . . . . . . . . . . . . . . . . . . o. 0.

Total energy requirement [bbl crude equiv.r . . . . . . . . . . . . 79. 11. 85:

Electricity sold to grid annually (MWhrentire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15.3

Annual ~k electricity d.nsond (kW, entire kiMiW)..... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23.5

- -–- — .—

L–. —. .

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars) b’

c

(Conventional r.ference system it SF-2)

Escalation of conventional energy costs

Constant red Energy pfiCO Energy price

energy fsric8s escalation I escakcction II

1. 1976 Startup

cr. Costs using sdor (ccwwewaticm) system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 215. (284.) 229. (297.)

Total with 20% ITC.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 196. (267.) 209. [280.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 170. (21 1.) 183. (225.)

b. Cosh usi~ convonticwxd mbmnce system . . . . . . . . 157. 187.

2. 1985 Stortupd

a. Costs using solar (comewation) system:

(capitol rekoted Cash. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154. [223.] 154. [223.)

(operation & mointenarsce costs) . . . . . . . . . . . . . . . . . . . . . . . 10. (10.) 10. [10.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o. (o.) o. (o.)

(electric bil~........... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 51. (51.) 72. p2.)

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 215. [2B4.) 236. [304.)

Total W,th 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 196. (267.) 217. [288.)

Total with full irscerstivos . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 170. (21 1.) 191. [232.)

b. Costs usihg ccwrventismalmti nce system . . . . . . . . /57. 204.

~ EFFECTIVE COST OF ENERGY TO CONSUMER

[Conventional reference system is SF-2)

283. (351.)

263. (334.)

238. (279.)

310.

154. (223.)

10. (lo.)

o. (o.)

156. [156.)

320. [389.)

301. (372.)

275. (316.)

395.

Type of incentives given

Levelized cost of solar energy No Full

or ‘conservation’ merg~ incentives 20% ITC incentives

$/MMBtu primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.55 (7.05) 3.83 (6.44) 2.89 [4.40)

C/kWh AticiN....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.36 (8.301 4.51 (7.58} 3.40 (5.18)

Escalation of conventional energy costs

COnstOnt real Energy price Energy price

Levdizedpnke paid k conventioncd energ~ energy prices escolatlon I escalation II

$/MAfBtsI M“mary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . 3.66 4.61 8.47

t/kWh A&i+... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.31 5.42 9.97
Table IV-31 .—Albuquerque: Solar Photovoltaic System—Single Family House Using Flat-Plate Air-Cooled Thin”Film Arrays

($0.10/Watt); Building Equipped With SF-2 Space-Conditioning

r 1 t 1

Grid MIX

Eleclr, uly Etec!r,c

Load

Pmwr

Photovoltalc (,onmllonmy

Array n 095

T,,ro,rw

Eieal)ng

Heal

,,,

P“rnfl 1111[2 COOlln~

Load

Water 1

supply tiw *

Hw

Heater Load

? n 75

1 I

A. ITEMIZED COST OF COMPONENTS

Unit First cost

Camfsanent

Annwl Life

Size Co$t (incl. O&P) O&M (yrs)

1. Heat Wmp... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 tans WOWtm $1,480 $50

2. DWWo&......................................,.,...........,.......,...... . . . . . . . — 425

$22Yea.

o ;:

3. Electric hat water hooter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 gal 225 0 15

4. Thin film madule (q =0.094) thin film @ 100 $/lkW. . . . . . . . . 106 m’ 25 $/ms ● 1,330 0 30

—Thin film @ 10 $/mi ‘1 ,330 0

—Instalbtion @ 8 $/m

15

—Shipping @ 2 $/mi

—25% overhead and profit

5. Power cditiWiW....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 kW 40 $/kW 400 4 30

6. Lightning Ptim. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 300 0 30

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $5,490 $54

● % installed Aectc.f cost oswmed replaced in 15 yrs., with total refdacemm t in 30 yrs.

ANNUAL ENERGY FLOWS

(Canventianal rcfermc e system is SF-2)

Energy COllWllOd Backup COflWIClOd W/ Energy SOVOd

by rd. Sy$tWl sabr/ccmsemOtion (% of totol)

Net Electricity (baught+ald) [MWh/unit),. . . . . . . . . . . . . . . . . . 32.5 13.0 59.9

Fuel consumed ansite [MMBtu/unit)... . . . . . . . . . . . . . . . . . . . . . . . o.

Totol energy mquirwnent (bbl crude ~uiv.p . . . . . . . . . . . . 79. 3:: 59:

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (DaUars)b’c

(Cocwmtbnal referenc ● system is SF-2)

Escalatim of canventianal energy costs

Cmstont real Energy @CO Energy fXiCt

energy prices escalation I ● Scabtim II

1. 1976 Startup

0. Costs using sabr (ccmsecvation) system:

Total with M incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 142. (169.) 160. [1B7.) 232. (259.)

Total with 20% ITC....................................,..... 137. [165.) 154. (182.) 226. (255.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 129. [149.) 147. (167.) 219.

b. Cosh using ~vmhbnaJmAence

(239.]

System . . . . . . . .

2. 1985 Startupd

157. 187. 310.

a. Colts using sabr (cmservatian) system:

(capital related casts) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66. (93.) 66.

(opemtim & maintenance costs] . . . . . . . . . . . . . . . . . . . . . . . 8.

(93.) 66. (93.)

(8.) 8. (8.) 8.

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o. (o.)

(8.)

(o.)

[electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 68. [68.) 9::

(0.)

(96.) 2::

Total with no incentive$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 142. (169.)

(208.)

170. (197.) 282. (309.)

Total with 20% IT.......................,.............. 137. (165.) 164. (192.) 276. [305.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 129. [149.) 157. (177.) 269.

b. Cosh using cmvmficmal mfemsm

[289.)

system . . . . . . . . 157. 20.4. 395.

C. EFFECTWE COST OF ENERGY TO CONSIJMER

(Cmventi.mal reference system is SF-2)

Type of itwentivos given

Lstvelized cost of sabr energy Na Full

or ‘comewatim’ energ~ incentives 20% ITC incentives

S/MMBm primary fowl...............................,...,, 1.77 (3.20) 1.48 [2.96) 1.11

C/kWh ekticiw........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.08

(2.16)

(3.771 1.75 (3.48) 1.31 (2.54)

Escalation of cm.entimccl ~ casts

Cmstant real Energy price Energy price

L@velized* paid b cmvenfional eneq#’” energy Pfices exalatim I escabtim II

Electricity Ad ta grid annually (MWh,entire biMiW]......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9.1

Annual -k electricity demand (kW, entire kiMiW).. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24.1

$/AiAf8hs primacy fssd........... . . . . . . . . . . . . . . . . . . . . . . . . . . 3.6d 4.61 8.47

$/k Wl &tii~.......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.31 5.42 9.97
Table lV-32.—Albuquerque: Solar Photovoltaic Cogeneration System —Single Family House Using One-Axis Concentrator

With Si Cells ($151Cells), Multitank Low-Temperature Thermal Storage; Building Equipped With SF-2 Space-Conditioning

::::;:’::; I

collect”, S“s!c.rr

Watef

S.L)Ply I H..,,.,,E, eel, I,

fi , ,.,

++++++ ‘ ~

 r “ “—-—

~

A,. !

— . . , . . -

m

A. ITEMIZED COST OF COMPONENTS

Unit First cost

Component

Annual Lif e

Size cost (incl. O&P) OdIM (yrd

1. Electric heat pump.... . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 tons 800 S/ton $1,480 $50 10

2. Ductwork . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 425 0 30

3. Muhitank electric hot water and storage . . . . . . . . . . . . . . . . . . . . . . . 200 kWh 3 $/kWh 600 0 30

A. Insulated ~teel ppe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125 ft 4.1 $/ft $513 0 30

5. l-axis trockmg ~ilicon module (cells cost $15,000/kW) 74 m’ 293 S/m* ● 1O,84O o 30

[7J=0.OW

——Tracking collectOr @ 130 $/m~ ● 10,840 0 15

——silicon concentrator cells @ 62 $/m*

—-Shipping @ 2 $/m*

——installation @ 40 $/m;

—Overhead and profit @ 25%

6 Pump~, controls and hat exchanger and miscollcmeous — — 500 0 10

equipment.

7 Thermol only collector area . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18 m’ 215 $/mz

.1 935 0 30

.1 935 0 15

8. Power conditioning . . . . . . . . . . . . . . . . 7 kW 222 $/kW 1,550 16 30

9. L!ghtning protection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 

— — 300 0 30

TOTAL....., . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $30,918 $66

● % installed collector cost astumed replaced in 15 yrs., with totol replacement in 30 Yrs.

ANNUAL ENERGY FLOWS

(Conventional reference ,y,tem is SF-2)

Energy COllSUmed 8ockup cocwmecl w/ E~rgy WVed

by ref. svstem sO&r/cOnsOwotti [% of total)

Net Electricity (bought-sokf) (MWh/unit)..........., . . . . . . . 32.5 2.4 92.7

Fuel consumed onsite (MMBtu/unit)... . . . . . . . . . . . . . . . . . . . . . . . o. 0.

Totol energy requirement (bbl crude equiv.~ . . . . . . . . . . . . 7:; & 92.7

Electricity mid to grid annuoily (MWh,entire kitiing)....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.7

Annual peak electriciw demand (kW. antim building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25.6

?g~--,h

-Q

n

.> .

‘-———--- --—— -—.7 l–— — - .— — -———= ‘y-=- ‘

‘i ~ - - - 3 Heal Pum D

..~-’ Compressor

MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b.

c

[Ccmve.tiocscd ref- e system is SF-2)

“( ‘.- . .

.=

B. LEVELIZED

Escobtion of COWWtiOIWl -y cosh

Constant NOI Energy price Energy price

● nofUY prices ascobtion I escalation II

1. 1976 .hwtuP

0. Costs using solar [consemotiosd system:

Total with ISO incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 362. (508.) 369. (515.) 395. (542.)

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 316. (469.) 322. (475.) 349. [502.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 255. (337.) 261. (344.) 288. (371.]

b. Cosh using ccuwntiomd refvmnca syaIwm....... 157. 187. 310.

2. 1985 StOrhSPd

a. Costs using sobr (conservation) system:

(copital *M costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 327. [473.) 327. (473.) 327. [473.)

(operation 6 maintenance cosh) . . . . . . . . . . . . . . . . . . . . . . . 10. (10.) 10. [10.) 10. (10.)

(fwl bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o. (o.) (0.) o. (o.)

(electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25. (25.) 3:: (36.) 77. (77.)

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 362. [508.) 372. [519.) 414. (560.)

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 316. (469.) 326. [479.) (521.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 255. [337.) 265. (348.) :E: (389.)

b. Costs using conventicmol reference system . . . . . . . . 157. 204. 395.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Convention reference system is SF-2)

TYW of incentives given

Levelixed cost of sob ● nergy No Full

or ‘conservation’ es’lergf incentives 20% ITC incentives

$/MMBtu p+mcsry fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10.04 (14.98) 8.47 (13.65) 6.41 (9,20)

$/kWh ~tici~......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11.81 (17.64) 9.97 [16.06) 755 (10.83)

Escabticm of conventional energy coth

Constant red Energy price Energy price

Levehzedprice paid for conventional eneq~’ energy prlce~ escalotlon I esccdotion II

S/MMBfCI pimty fowl. . . . . . . . . . . . . . . . . . . . . . 3.66 4.61 8.47

~/k Wh ebctntiity..... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.3/ 5.42 9.97
/!.// l/////// l

Q

Table IV.33.—Albuquerque: Conventional System— Insulated Single Family All Electric House With Heat Pump Heating (IF-2)

A

El---

m

r

— EIPLI, IL WA

Hw

~

* Loaa

;q”:j

L 1

A. ITEMIZED COST OF COMPONENTS

Unit First cost

Component

Annual Life

Size cost (incl. O&P) o&M [yrs)

1. Heat pump . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.3 tons Soo $/ton $1,040 $50 10

2. DvcWo&.......:................................,...................... . . . . . . . . . . . — — 425 0 30

3. Electric water heater . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 gal 225 ea. 225 0 15

4. Extra insulation, storm doors and windows...., . . . . . . . . . . . . . . . . . . — — 981 0 30

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $2,671 $50

ANNUAL ENERGY FLOWS (Conventional reference system is IF-2)

Energy CCM3UM0d Backup ccmsumssd w/ Emergy saved

by ref. system sOlar/conservation (% of total)

Net Electricity (bought-sold) (MWh/unit].. . . . . . . . . . . . . . . . . 28.0 28.0 0.

Fuel consumed cmsite (MMBtu/unit).................,,....... o. 0.

Totol energy requirement (LAd cm& ~uiv.y . . . . . . . . . . . .

0.

68. 63. 0.

Electricity sold to grid annually (MWh,entire kiting)........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Annual peak ebctiicity demand (kW, entire kiMiW)................................................................., . . . . . . . . .

0.

22.1

-’7 -

\

= Outside

jj!-”!k t+eatEx~hanger

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b”c

(Conventional reference system is IF-2)

Escalation of corwentiwml energy costs

Constant real Energy psice Energy price

energy prices escalation I escabticm II

1. 1976 Startup

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 142. (155.) 168. (181.) 275. (289.]

Total with 20% ITC............ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 142. [155.) 168. (181.) 275.

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 142.

(289.)

(155.) 16s. (181.) 275. (289.]

2. 1985 startup~

(capitol rebted costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32. (46.) 32. (46.) 32. (46.)

(opemtion & maintenance cost$) . . . . . . . . . . . . . . . . . . . . . . . 7. r.] 7. (7.)

(fuel bil~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o. (o.)

(7.)

o. (0.) :: (o.)

(electric billl . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 102. (102.) 143. [143.] 311.

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 142. (155.)

(31 1.)

183. (196.) 350. [364.)

Total with 20% IT.................., . . . . . . . . . . . . . . . . . . . 142. (155.) 183. [196.) 350. (364.)

Total with full incentive . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 142. [155.) 183. (196.) 350. [364.)

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system is IF-2)

Type of incentives given

Levelized cost of solar energy No Full

a ‘cocuecvatioo’ erser~ incentives 20% ITC incentives

$/MMBtu primary fuel...........,......., . . . . . . . . . . . . . . . . . . N / A (N/A) N / A (N/A)

@/kWh e&hici~.............................................,

N / A

N / A (N/A)

(N/A)

N / A (N/A) N / A (N/A)

Escabtion of conventional energy costc

Constant real Energy price Energy ~CO

[evelizedprire ~id for conventibmd errerg#’e energy prices escalation I escalation II

$/hfhfehl p“mqv fowl. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.72 4.d8 a d o

~/k Wh ektiki~........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.38 5.51 10.12
Table lV-34.— Albuquerque: Solar

m

Photovoltaic System— Insulated Single Family House Using Flat-Plate Air-Cooled Silicon Arrays

($0.50/Watt); Building Equipped With IF-2 Space-Conditioning

c1

I) &-l---a (

,-. .>

1 I u~ C, OmLlressor

A. ITEMIZED COST OF COMPONENTS

Unit First cost Annual Life

Component Size cost (incl. O&P) O&M (yrs)

1. Heat pump . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.3 tons 800 $/ton $1,040 $50 10

2 Ductwork.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 425 0 30

3. Electric hot water . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 gal $225 ea. 225 0 15

4. Air-cooled tilicon PV [500 $/kW) [q = O 12) . . . . 59 m’ 88 $/m’ “2,600 o 30

——Silicon array @ 60 $/mz ‘2,600 o 15

—Shipping @ 2 $/m*

——installation @ 8 $/m~

—25% overhead and profit

5. Power conditioning . . . . . . . . . . . . . . . . . . . . . . . . 7.6 kW 113 859 9 30

6. Lightning protection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 300 0 30

7. Extra insulation, \tonn doors and windows . . . . . . . . . . . . . . . . . . . . . . . — — 981 0 30

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ..... $9,030 $59

● % !nstcdled collector cO~t assumed replOced in 15 YrS- with tOtal replacement in 30 yr~

ANNUAL ENERGY FLOWS

[Conventional reference system is IF-2)

Energy consumed Backup consumed w/ Energy saved

by ref. system sc.10r/cOnsewOtiOn (% of total)

Net Electricity (bought-wId) IMWh/unit). . . . . . . . . . . . . . . . . . . 28.0 13.4 51.9

Fuel consumed orwite (fiM8tu/unit). . . . . . . . . . . . . . . . . . . . . . . . . . o. 0. 0.

Total enera~ requirement (bbl crude eauiv.r . . . . . . . . . . . 68. 33. 51.9

Electricity sold to grid onnmtly [MWh,entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.7

Annual oeak electrici~ demand (kW. entire buikfirw) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19.6

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars) b’

c

(Conventional reference syttem is IF-2)

Escalation of conventional energy cost$

Constant real Energy price Energy price

energy price~ escolcction I escalation II

1. 1976 Startup

cc. Costs using solar (cocwewatiocd system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 172. (214.) 189. (231.) 258. (301.)

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 161. (206.) 178. (223.) 248. (292.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14a. (176.) 165. (194.) 234. (263.)

b. Costa using ccmventiomd reference system . . . . . . . . 142. 168. 276.

2. 1985 startcJp~

cc. Colts using *rlcon=tvotion) SyStam:

(capitol related Cash. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 97. [140.) 97. (140.) 97. (140.)

(operation & maintenance costs] . . . . . . . . . . . . . . . . . . . . . . . 9. (9.) 9. (9.) 9. (9.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o. [0.) o. (0.) o. (0.)

(electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66. [66.) 92. (92.) 200. (200.)

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 172. (214.) 198. (241.) 306. (349.)

Totol with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 161. (206.) 188. (232.) 296. (340.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 148. (176.) 174. (203.) 282. [31 1.)

b. Cosh using cwrvenfioncd reference system . . . . . . . . 142. 183. 350.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system is IF-2)

TYOO of incentives given

Levelized cost of solar energy No Full

of ‘corwervation’ energ~ incentives 20% ITC incentives

$/MMBti primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.62 (7.62) 3.91 (7.01) 2.96 [4.97)

C/kWh ektiici~....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.U (8.97) 4.60 (8.25) 3.49 (5.85)

Escalation of conventional energy costs

Canstcmt reOJ Energy price Energy price

le.elizedprke paid for conventional energ~e energy prices escalotlon I escalation II

$/AfMBhl p“lnary till.............................,........ 3.72 4.68 8.60

@Wh e&ctnkify....................,.......... . . . 4.38 5.51 10.12

o

●

4

m
Table IV-35.-Albuquerque: Solar Photovoltaic System— Single Family House Using Flat-Plate, Air-Cooled Silicon Arrays ($0.50/Watt),

Battery Electrical Storage; Building Equipped With IF*2 Space-Conditioning

k5-J-==

EEl-++Esl-

(7(’ “ ) h Heal Exchangel

LY1[ll[ll[L

c l

~—--–.-f =-..

Turn, ne Heat Pump

Compressor

A. ITEMIZED COST OF COMPONENTS B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollam)b”c

(C~venti~l referee system is IF-2)

Unit FirM cost Annucd Life

component Size cost (incl, O&P) O&M (yT\) Escalation of conventional energy cosh

Constant real Energy price Energy price

energy prices escolatioo I escoloticm II

1. Heat pump . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.3 tons 800 $/ton $1,040 $50 10

2. DucW&...................................,............................... . . . — — 425 0 30

3. Electric hot water . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 ml S225 eo. 225 0 15

4. Air-coded silicon PV (500 $/kw (q = 0.12) . . . . . . . . . . . . . . . . . .

—Siliccm array @ bo $/m’

——Shipping @ 2 $/m’

—Instollotion @ 8 $/m*

——25% overhead and profit

5. Power cditi~iW. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6. Lightning p*tiw. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7, 8atie&s........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

8. Extra insulation, storm doors and windows . . . . . . . . . . . . . . . . . . . . . . .

59 ;’ 88 S/m’ ● 2,boo

‘2,600

o 30

0 15

1. 1976 Shcrtup

a. Costs using solar [conservation) system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20% ITC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Costs using ccwrventic+ml reference system . . . . . . . .

2. 1985 stortup~

0. Cosh using *r(consewotion) tystem:

(capitol related casts . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

(operation & maintenance costs] . . . . . . . . . . . . . . . . . . . . . . .

(fuel billJ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total with no incentive . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20% ITC.......................,............,.....

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Cosfs using conventicmol mfemnce system . . . . . . . .

192. (243.) 207. [259.)

179. (232.) 195. (248.)

163. (197.) 179. [213.)

142. 1C$8.

272. (323.)

260. (313.)

243. (277.)

7 kW 114 800 276.

— — 300

20 kWh 70 kWh 1,400

— — 981

8 30

0 30

4 10

0 30

E

121. (172.)

9. [9.)

o. (0.)

61. [61.)

192. (243.)

179. [232.)

163. (197.)

142.

121. (172.]

9. (9.)

o. (0.]

86. [86.)

216. (267.)

204. (257.)

188. (222.)

183.

121. (172.)

9. (9.]

o. (o.)

186. (186.)

317. (368.)

304. (357.)

288. [322.)

350.

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . .... . . . . . . . . . . . . . .. . . . $10,371

C. EFFECTIVE COST OF ENERGY TO CONsUMER

(Conventional reference system is IF-2)

Type of incentives given

Levelized cost of WJlar energy No Full

or ‘conservatica’ energ~ incentive~ 20”4 ITC incentive,

$/MM6h primory fuel.........,.,,, . . . . . . . . . . . . . . . . . . . . . . . 7.30 (1 1.43) 6.31 (10.58) 4.W

t/kWh e&*ici~. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (7.75}

8.60 [13.45) 7.42 [12.45J 5.88 [9.12)

Escalation of conventional energy cost~

Constant real Energy price Energy price

[evelizaci prire poid for convenhbna[ energ#e energy @cat e$colaticrn I escalation II

s/MMBhJ p“moy fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.72 4.68 8.cW

t/k Wh ehti"ci~....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.38 5.5J 10. J2

● % installed collector cost awmed reploced in 15 yrt., with totol replaament in 30 ym

ANNUAL ENERGY FLOWS

(Conventional reference system is IF-2)

Energy CIX18Umed Backup COtCWWd W/ Enewy SOVed

by ref. system sOlor/cOnse?votion (% of totol)

Net Electricity (bought-sold) (MWh/unit)... . . . . . . . . . . . . . . . . 28.0 15.3 45.2

Fuel consumed omite (MM5tu/unit)... . . . . . . . . . . . . . . . . . . . . . . . o. 0.

Total erwgy requirement (bbl crude equiv.p . . . . . . . . . . . . b8. 3;: 45.2

Electricity wld to grid annually (MWh,entire buiMiW)........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .1

Annual peak electricity demcmd [kW, entire hiMiN). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19.6
Table lV”36.—Albuquerque: Solar Photovoltaic System —Insulated Single Family House Using Flat-plate Air-cooled Silicon Arrays

($0.50/Watt); Building Equipped With Improved IF-2 Space-Conditioning

m’‘d““

I

I

F=-’--

—J

.

(lutslde

Heat Exchanqer

Compressor

MONTHLY COSTS PER UNIT TO CONSUMER

(Coswentimal reference system is IF-2)

A. ITEMIZED COST OF COMPONENTS -

Unit Fimt cost

Component

Annual Life

Size cost (inCl. O&P) O&M (yin)

(Dollars) b.

c

B. LEVELIZED

Escabtion of conventional sm.rgy costs

Constont real Energy price Energy price

1. tieot pump . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.3 OIWOY ~e~ escabtion I escalation II tom 960 s/tocl $1,250 $50 10

2, Ductwork . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — 425 0 30

3. ElectTIc hot water . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 gal $227W. 225 0 15

4. Air-cooled silicon PV (500 $/kw) (q= 0.12).......... . . . . . . . . . . . . 59 m’ 88 $/m’ ‘2,600 o 30

—Silicon army @ 60 $/m* “2,600 o 15

——Shipping @ 2 $/m’

—Installation @ 8 $/m’

1. 1976 StOrtUP

0. Costs using sabr (conservation) system:

Totol with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 166. [210.) 181. (225.)

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 156. (201.) 171. (216.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 142. (171.) 157. (186.)

b. Costs using conventil drrmsce systwn........ 142. 168.

2. 1985 stortup~

0. Costs using salor (consewotion) system:

(copitcsl related costs] . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100. (144.) 100. [144.)

(operation 6 mointencmce COSN) . . . . . . . . . . . . . . . . . . . . . . . 9. (9.) 9. (9.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (o.) [0.)

(electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5;: [57.) 8! (81.)

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 166. (210.) 189. [233.)

Total W,th 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 156. [201.) 179. (224.)

Total with full i~antives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 142. [171.) 165. [195.)

b. Costs using cmwtiasrdrefemnce system . . . . . . . . 142. IW.

~ EFFECTIVE COST OF ENERGY TO CONSUMER

(Cocsvesstimd mfermca system is IF-2)

242. (286.)

231. (277.)

218. (247.)

——25% 276. overheod ond profit

Power conditioning . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 kW 114 800 8 30

Lightning pr:ttitlon. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . —

— 300 0 30

Extm insulation, storm doors and windows . . . . . . . . . . . . . . . . . . . . . . . — — 981 0 30

5.

6.

7.

—

100. (14.)

9. (9.)

o. (o.)

175. (175.)

284. (328.)

273. (319.)

260. [289.)

3s0.

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

$9,181 $58

I

● % instalbd collectOr cOst assumed redoced in 15 yrs., with totol replacement in 30 Yrs.

ANNUAL ENERGY FLOWS

(Conventional reference system is IF-2)

Type of incentives given

Lmdixed cost of solar ● nergy No Full

or ‘conservation’ enOr# incentives 20% ITC incentives

$/MMBtu @mV fad.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.11 (6.72] 3.49 (6.19) 267 (4.42)

Enwgy COSSSIJmOd Bockup COMtlWlOd W/ hecuy SOVOd t/kWh el~tici~. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.84 (7.91) 4.10 (7.29) 3.14 (5.20)

by ref. SyStOm sabr/cOnsewatim [% of total)

Net Electricity (bought-sold) (MWh/unit)..... . . . . . . . . . . . . . . 28.0 10.9 61.2

Fuel consumed onsite (MMBtu/unit)... . . . . . . . . . . . . . . . . . . . . . . . o. 0.

Totol energy requirement (JAJI crude equiv.~ . . . . . . . . . . . . 68. 2;: 61.2

Electricity sold to grid cmnually (MWh,entim buildng) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6.7

Annwl peak electricity demand lkW, entire kiMiW)......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16.7

Escddkx of conventional energy costs

Constant real Energy price Energy price

LeveJizadprice poid for conventional eIwrg~* energy prices escolotion I escalotlon II

$/MAf8hl @-v ~1................ ~~ ~~• ~~~~~Ç3•Œ• ́•0• ́• ú3• ̈GÊ‡„ç_• 3.72 4.68 8.60

t/kWh okctricity.....................,. 4.38 5.51 10.12
Table lV-37.—Albuquerque: Solar Photovoltaic System— Insulated Single Family House Using Flat”Plate Air. Cooled Thin-Film Arrays

($0.30/Watt); Building Equipped With IF-2 Space-Conditioning

M SL

+ ml f, [ Ed== Load

Pho!ovoltalc

Panels

<-- ”

~..% 8

T

~1 Ii i II 1, 1! ,1 ‘ ..:~ -

‘ L-J

)utslde

>;&j;,]) ‘eatExcha n g

e

--3--”-’

———/” Heal Pump I

supply

I ‘1,!;;: ,+Z!!I Compressor

1 I

A. ITEMIZED COST OF COMPONENTS B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b

”

c

(Ccmventianal mfemnce system i, IF-2)

Escokatica of conventional energy costa

Constant raal Energy price Energy price

energy prices escakaticm I escalation II

1. 1976 startup

a. Costs using solar (canservotian) system:

Total with na incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 149. [175.) 169. (195.) 253. (279.)

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 4 . (171.) 164. (191.) 248.

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 138.

(275.)

[157.) 158. (178.) 242. [262.)

b. Costs using conventional mfererue system.....,., 142. 168.

2. 1985 Stortupd

276.

a. Costs using wdcrr (can$eryatian) system:

(capital related costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 61. (87.) 61. (87.) 61. (87.)

(apemtic+ & maintorrance costs) . . . . . . . . . . . . . . . . . . . . . . . 8. (8.) 8. (8.) 8. (8.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o. (0.] o. (o.) o. (o.)

(electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 79. (79.) 112. [1 12.) 242. (242.)

Total with na incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 149. (175.) 181. (207.) 311. [337.)

Tatal with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 4 . (171.) 176. [203.) 306. (333.)

Tatal with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 138. {157.) 170. (189.) 300. (320.)

b. Cosh usihg canvenfiand reference system . . . . . . . . 142. 183. 350.

Unit First cost Annual Life

Campc.nent Size cast [incl O&P) O&M fvrd ., ,

1. Electiic heat prep. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.3 tans $800 $1,040 $50 10

2. DucWo&........,.................................,.................... . . . . . . . . . . .

3. Electric water heater . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

4. Thin film module (q = .073) 300 $/kW . . . . . . . . . . . . . . . . . . . . . . . . . —Thin film @ 22 $/m*

— . 425 0 30

40 gal 225 ea. 225 0 15

53 m’ 40 “ 1 060 0 30

‘ 1 060 0 15

—-installation-@ 8 $/m*

—-Shipping @ 2 $/m’

—-257. overhead and prafit

5. Power conditioning... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

6. Lightning pmt~tim... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

7. Extra insulation, starer dcrors and windaw$........ . . . . . . . . . . . . . . .

4.3 kw 118 5 30 — — s?; o 30 — — S981 o 30

. ‘ z Installed collector cost assumed replaced [n 15 yrs with total replacement (n 30 yrs

C EFFECTIVE COST OF ENERGY TO CONSUMER

(Canventicrrd reference $ystem is IF-2)

Type of incentives given

ANNUAL ENERGY FLOWS

(Carrventi.xd refwercce system is IF-2)

Levelized coat of Ar energy Na Full

of ‘corwewation’ energy’ incentives 20% ITC incentives

s/MM8hl primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.66 (6.95) 3.07 (6.45) 2.29

t/lcwh e&tiiciw. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.30 (8.18)

(4.77’)

3.61 (7.59) 2.70 [5.62)

EscakctiarI of canventianal energy cows

Energy COMIJmOd Backup COIWUrllOd W/ Er’rer.Jy $OWd

by mf. system saiar/cOnsOwatian [’Y. of tatal)

Net Electricity (baught+ald) (MWh/unit).... . . . . . . . . . . . . . . . 28.0 19.8 29.1

Fwl consumed ansite (MMBtu/unit)..............,........... o. 0.

Totccl energy mquir enmnt (bbl cti Oquiv.r . . . . . . . . . . . . 68. 49. 29°i

Electricity Ad to grid annually (MWh,entim building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Annual peak ● lectricity demamd (kW, entire hiMiW)......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2:::

Canstant real Energy price Energy price

levelizedprice paid for conventional erreW~.* energy prke$ escalatiafr I escakctiaa II

$/A4M8h ~mv fad..............,.,..................,. 3.72 4.68 8.60

$/k Wh ek~i&.......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.38 5.51 10.12
V-38.—Albuquerque: Solar Photovoltaic System—Insulated Single Family House Using Flat-Plate Air-Cooled Thin-Film Arrays

($().10IWatt); Building Equipped With IF-2 Space”Conditionin9 . . Table

m

‘h---, ‘Ca’’’cha”e’ -.

‘1 ,<.+ , tiw “’”’E’’”’””’” m L ,,ad 1 ‘x -1-,

—... -— Heat Pump

Compressor

MONTHLY COSTS PER UNIT TO CONSUMER

c1 I I

B. (Dollors)bc LEVELIZED A. ITEMIZED COST OF COMPONENTS

(Conventional reference sy,tem is IF-2)

Unit First cost Annual Life

Size cost (incl. O&P) O&M [yrS.)

1.3 tons $800 $1,040 $50 10

— — 425 0 30

Escokrtion of conventional energy cosh

Component

1. Electric heat pump..... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

2. Ductwork . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3. Electric water hooter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

. . . . . . . . . . . .

4. Thin film module (TI = 0.94) 100 $/kW . . . . . . . . . . . . . . . . . . . . . . . . .

—Thin film (61 10 S/m’

Constant real Energy price Energy price

el’lergy pticos escalation I escalation II

40 QOl 1 1976 Startlm 225 w 225 0 15

53 mm’ 25 .66 3 0 30

.663 0 15 0. Co$ts using solar (consewotid systenr:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 132. (154.) 152. [173.) 23a [251.)

Total with 20% IT.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 129. (151.) 149. (170.) 227.

Totol with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

[249.)

125. (143.) 145. [162.) 223. (24a)

b. Co.h using conventional mf.rerue system . . . . . . . . 142. 168. 276.

--

—-insulation @ 8 $/m’

——Shipping 22 $/m’

—-25% overfwod and profit

S. power conditi~ing.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

5.5 kw 40 220 2 30

6. Lightnjng ~t.ction. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . —

— 300 0 30

7. Extra msulotmn, ttOrm doors and windows . . . . . . . . . . . . . . . . . . . . . . . — — 981 0 30

2. 1985 Stortu;d

a. Costs using solar (comefvotion) system:

(copital related Cost*) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

(OPOMtiOII & ~intO~nce cOStS) . . . . . . . . . . . . . . . . . . . . .

(fwl bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Ielectric, bill) ...:. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total wth no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20% IT.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Costs using conventional mfemnce ~ystem........

50. (72.)

8. (8.)

o. (0.)

74. (74.]

132. [154.)

129. [151.)

125. (143.)

142.

50. (72.)

8. (8.)

o. [0.)

104. (104.)

162. [184.)

159. (181.)

155. (173.) 183.

50. (72.]

8. (8.)

o. [0.)

226. [226.)

284. (306.)

281. (303.)

277. (295.)

330.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

. ,, installed Collector cost assumed rePlaced In 15 Yrs WIttI tOtal replacement In 30 YrS (Ccmventiomd mf erenco system is IF-2)

Type of incentives given

ANNUAL ENERGY FLOWS

(Conventional reference aystem it IF-2)

Lev,elized cost o! mJar energy No Full

cu cotworvaticw efcurgyc incentives 20% ITC incwrtive~

$/MMBm prirnory fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.77 (3.85) 1.48 (3.61) 1.10 (2.79)

*/kWh ektilCl~. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.08 [4.53) 1.74 [4.24) 1.30 [3.28) Energy consumed Bock.p cocwumed W/ Enew SOV.d

by mf. systwn u+Or/consolation (% of rotol)

Net El~ticity [bught-dd) [MWh/unit)..... . . . . . . . . . . . . . . 28.0 17.5 37.5

Fwl ~o”su~ ~site [MMBtu/unit)... . . . . . . . . . . . . . . . . . . . . . . . o.

Total energy require~t (~ cd Wuiv.~ ---

2: 43. 37°5

Ektricity Ad to grid annually (MWh,entire building) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.9

Awl pcik electrici~ d.mo~ (kW, ~fim ki~iW)........................"."..".."".-""""""..."....-"""""""""-"""""""." -

19.9

T. - -- ,

Escalation of conventional energy costs

Constont real Energy price Energy price

Lov.ii.edpnke pnti tin conventional mmv#”O energy prices escalation I escalation II

$/MA46hI W“hWY w.... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.72 4.d8 8.60

t/k Wh ektii*........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.38 5.51 10.12
Table IV-39.—Albuquerque: Solar Photovoltaic System —lnsula

($O.IO/Watt); Building Equipped Y

r=l

m+z?

:ed Single Family House Using Flat-Plate Air. Cooled Thin-Film Arrays

!ith Improved SF.2 Space-Conditioning

A. ITEMIZED COST OF COMPONENTS

Unit First cost Annual

component

Life

Six. cost (i~l. O&p) O&M [yrs)

1. Electric heat Wmp.... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.3 tons 960 $/tcnl

2. DUchd.......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . —

$1,250 $50 10

425 0 30

3. Electric water heater . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 oss1 $22Ye0. 225

4. Thin film module (q= O.094) 10s3 $/kW ... 53 m’ 25 $/ms ● 663

—Thin film @ 10 $/mi

: ;;

● 663 o 15

—Instolloticm @ 8 $/mz

—Shipping @ 2 $/ma

—25% ovotfwod and profit

5. Power cditiiW... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5 kW 40 $/kW 200 2 30

6. Lighttsi~ ~t~tia. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .— — 300 30

7. Extm insulation, storm doors and windows . . . . . . . . . . . . . . . . . . . . . . . — — 981 : 30

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $4,707 $52

* % installed collector cost alsumed replaced in 15 yin., with total repkocemcnt in 30 yra.

ANNUAL ENERGY FLOWS

[conventional referenc e system is IF-2)

Energy cOtMUtWd Backup COtlSUmOd w/ Energy soved

by ref. tytt~ mlor/ccmsewOtiOn (% of totol)

Net Electricity (bought.+ (MWh/unit)..........,...,.... 28.0 15.0 46.2

Fuel consumed otwito (MMBtcs/unit).. . . . . . . . . . . . . . . . . . . . . . . . .

Total energy requirement (bbl crude equiv.~ . . . . . . . . . . . . 2: 3;: 46:

Electricity sold to grid onnually (MWh,entire kiMiW)......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.9

AMuol peek electricity demand [kW, retire hiMiW)......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17.0

1 ~\\\.~.\.’.\

anger

\ -———L—J \—F~ Heat PumD

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dallars)b’c

ICcmventionol r.fwence svstem is IF-2)

Escobtion of ccmvonticmol energy costs

Constant real Energy priCc Etwgy price

energy prices esusbtion I escobticm II

1. 1976 Stortup

0. Costs using sokor (conservation) system:

Totol with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 128. (151,) 145. (168.) 215.

Totcsl with 20Y. ITC............ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125. (148.)

(238.)

142. (165.) 212. (235.)

Totol with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 120. (139.) 138.

b. Cosfs using cmweniioswl reference

(156.) 208. (226.]

Slum. . . . . . . . 142. 168. 276.

2. 19s5 statiup~

o. Cosh using solar (conservation) system:

(capitol related corm. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 54. (77.) 54. ~.) 54. 177.)

(oporoticm & maintencmcc costs) . . . . . . . . . . . . . . . . . . . . . . . 8. (8.) 8. (8.) 8. (8.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o. [0.) o. (0.)

(electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66.

(0.)

[66.) 93. [93.) 20;: (202.)

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 128. (151.) 155. (177.) 264. (286.)

Totol with 20% IT.............., . . . . . . . . . . . . . . . . . . . . . . . 125. (148.] 151. (175.) 260.

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 120. (139.)

[283.)

147. (165.) 256.

b. Costs using conswfionol mfbsenm system., . . . . . . 142.

(274.)

183. 330.

C EFFECTIVE COST OF ENERGY TO CONSUMER

(CcMventioncYl reference system is IF-2)

Type of incentives Oivon

Levelized co~t of zolcsr ~ No

or ‘conservation’ en.rg#

Fufl

incentives 20% ITC incentives

$/MMbJ phOV fad.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.71 [3.50) 1.46 (3.28) 1.12 (2.55]

$/kWh ektici~........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.02 (4.12) 1.71 (3.86) 1.31 (3.00)

Escobtion of COIWOtltiOd enetuY costs

COcsstont real Energy price Energy price

Levelizedprice paid for coswenhboal escesg~.e energy prices e=abtion I escabtion II

$/MMBhI p“mary &l... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.72 4.68 8.60

C/kW% ktii~.......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.38 5.51 10.12
Table IV-40 .—Albuquerque: Solar Photovoltaic Cogeneration System— Insulated Single Family House Using One-Axis Concentrator

With Si Cells ($151Watt cells), Multitank Low-Temperature Thermal Storage; Building Equipped With IF-2 Space. Conditioning

— 7

,

\

. , ——.— ——4

1’=.—= T=F=- “===

i,-

‘1 I .

,, ~,, ,1, , r - l I

I I

.,

,., ,

7zzzLnz

—-

 - )

.

,, /- tied! ?drnp

‘.=.l.

.

,.,

..--- ’ c0rTprY5su,

CIl

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b’

c

A. ITEMIZED COST OF COMPONENTS

(Conventional reference system is IF-2)

Companent

1. Electric heat pump.,.

2. Ductwork . . . . . . . . . . . . . . . . . . . .

3. Multitank electric hot water and jtomge. . . . . . . . . . . .

4 Insulated steel pipe . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

5 l-axis hocking silicon m~uIe (.eIIS ~o,t $15,000/kWJ

(n = 0.099).

Size

Umt

cost

964) $/ton

—

3 $/kWh

4.1 s/ft

293 $/mz

Fwst coft

(incl, O&P)

Annual Lif e

O&M (yin) Escalation of conventional energy costs

Constant real Energy price Energy price

1.3 tom $1,250 energy prices escalation I escalation II

425

m

513

‘54,201

$50 10

0 30

0 30

0 30

0 30

200 kwh

125 ft

37

1. 1976 Startup

a. Costs using sofar (conservation) system:

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20% IT.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Cods using corwe.tioncd mferwnce system . . . . . . . .

2. 1985 Startupd

a. Costs using solar (conservation) system:

(cap,tal related costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

(operation & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . .

(fuel btll) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

(electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 207. IT.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Totctl with full incenfive~ . . . . . . . . . . . . . . . . . . . . . .

b. Cosh using conveflfi-1 mfem~e system . . . . . . . .

235. (323.)

210. [302.)

153. (230.)

142

244. (332.)

219. (31 1.)

162. (240.)

Ids.

281. (370.)

256. (348.)

IW. (277.]

275.

—~Trackmg collecto, @ 130 $/mI

——SllicOn concentrator ~ells 62 $/mz

——$hlpplnc @ 2$, ~i

——install rton @ ~ $/m*

——Overhead and ~ofit @ 25”/.

6. Pumpt, controls and ~t ● xchoWr and miscellaneous

equipment

7. Thermal only collectW ~ti . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

‘54.201 o 15

191. (279.)

9. (9.)

o. (o.)

35. (35.)

235. [323.)

210. (302.)

153. (230.)

142.

191. (279.)

9. (9.)

(o.)

;: (50.]

249. (337.)

224. (316.]

167. (245.)

Iw.

191. [279.)

9. (9.)

o. (0.)

108. (108.)

307. (395.)

282. (374.)

225. [303.)

350.

— 0 10

9

4 kw

—

215 $/m’

233 $/kw

—

.968

.968

932

300

981

0 30

0 15

9 30

0 30

0 30

8. Power conditioning . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

9. Lightning protection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

10. Extra inwdation, storm doort ond window!

C. EFFECTIVE COST OF ENERGY TO CONSUMER

IConve.tied reference system is IF-2)

Type of incentives given

Levelized cost of 801ar ● rwgy No Full

m ‘consewation’ enerd incentives 20% ITC incentives

● % installed collector cost assumed replaced m 15 yrs., with totol re+cement in 30 yr~.

ANNUAL ENERGY FLOWS (Conventional reference system is IF-2)

-—.

Energy consumed Backup conmnned w/ Energy saved

by ref. system sOiOr/conservation (% of total)

$/MMBtu primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7.60 (1 1.80] 6.41 (10.78) 3.71 (7.40)

t/kWh ekticiW. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.95 [13.89) 7.55 (12.69) 4.36 [8.70)

Escalation of conventioncd energy colts

—

Constant real Energy price Energy price

Levelized#ce paid b conventional energ~e energy price! escalation I escalation II

$/MMBru prr”~ry Fuji. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.72 4.da E.@

$/kWh .bcfnctty...... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.38 5.51 10.12

...——

Net Electricity (krought~~ (MWh/unit). . . . . . . . . . . . . . . . . . . 28.0 6.5 76.7

Fuel cormmnrd onslte (AM8tu/unit)... . . . . . . . . . . . . . . . . . . . . . . . o. 0. 0.

Total energy require~tt (bbl crude equiv.~ . . . 68. 16. 76.7

Electricity sold to grid mnually (MWh,entire kiUi~)......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.0

Annual peak electricity Arnand [kW, entire buildiW)....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17.7
Table lV-41.—Albuquerque: Solar Photovoltaic Cogeneration System—insulated Single Family House Using Plastic Dye Photovoltaic

Concentrator Multitank Low. Temperature Storage; Building Equipped With IF.2 Space-Conditioning

m mGw2 Mmc

Elec!r,c,k Emctr,c

Lcdo

1

Cono hone, t- 1

i

/

c“nc’n’’”’’”+%l%r——r—— Therma, . W F!ec, r,c

Cime.tor Systev

Waler Imomvea Hw sum , Mw . ‘xc

Hea!e. IElec,., c, —

A [ ,- ,,

, v. 975!

+tw+H++ -‘“’

cl

-- .5..,

A. ITEMIZED COST OF COMPONENTS

Unit First cost Annual

Campanent

Life

Size cost (incl. O&P) O&M (yrs)

1. Electric heat ~mp. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2. Ductio&......., . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

3. Electric hot water ond multitonk law temperature storogsr

4. Insulated steel pipe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5. Nontrocking 10OX plast}c concentrator with 30”0 efficient

cells.

—-Plexiglass and dyes @ 45 $/ma

—Calls @ 15 $/mz

—-Shipping @ 2 $/ma

—Installation @ 20 $/mz

——25% overhead and profit

6. Pumps, cantrals, and heat exchonger . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

7. Power c~ditioning.... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

8. Lightning prot.tion...... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

9. Extra insulation, starm band windows . . . . . . . . . . . . . . . . . . . . . . .

1.3 tons

—

200 kwh

125 ft

38 m*

—8.5 kw

—

—

800 $/ton

—

3 $/kWh

4.1 $/ft

103 $/ms

— 53 $/kW

—

—

$1,040

425

600

513

● 1,960

● 1,960

500

450

300

981

w) 10

0 30

0 30

0 30

0 30

0 15

0 10

7 30

0 30

0 30

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $8,729 $57

● % instollad ccrllectar cost assumed raplcrced in 15 yrs., with totol replacement in 30 ym

ANNUAL ENERGY FLOWS (Ccmventictnol reference system is IF-2)

Energy COllSUICd Backup COSMUld W/ Energy =Ved

by ref. $y8tem sabr/carsservatiall (% of totol)

Net Electricity (baught.said) (MWh/unit)..... . . . . . . . . . . . . . . 28.0 2 100.8

FueIl ccmswned amite (MMBtu/unit)..................,.......

-.

0. 0.

Total energy requirement (bbl crude equiv.r . . . . . . . . . . . . 2: -1. 100.8

Electricity said ta grid onnuolly (MWh,entim kiMiW)......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9.5

Annual peak efectckity deasond (kW, entire kiMiW)......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19.8

q

1i Unit

Hot Water

Storage

——’———/ Heat Pump

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b’

c

ICanventbnal mfemnce system is IF-2)

Escalation Of COllVeCStiOd _COStS

Catwtant real Energy price Energy price

energy prices escalation I escabtian II

1. 1976 Startup

a. Costs using *r(canservatian) system:

Total with na incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 124, (166.) 129. [171.) 153. (195.}

Total with 20% IT..........................,........... 114. [157.) 120. [163.) 143. (187.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 92. (130.) 98. (135.} 121.

b. Cosh using canventkxwd Iwfemnce system . . . . . . . . 142.

(159.)

168.

2. 1985 startup~

275.

a. Cosh using sabr (consewatic+) system:

(capitoi mbted Cash....................................,. 93. (135.) 93. (135.) 93. (135.]

(aperoticm & mointenana costs) . . . . . . . . . . . . . . . . . . . . . . . 8. (8.) 8. (8.) 8. (8.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o. (o.] (0.) (0.)

(electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22. (22.) 3:: (31.) 4: [be.)

Total with na incentive~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 124. (166.) 133. (175.} 170. (21 1.)

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 114. (157.) 123.

Total with full incesctivea

(166.) 160.

92. (130.)

(203.)

. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 101. (139.) 138. (175.)

b. c%h using canwnticwral refemncs system . . . . . . . . 142. 163. 3s0.

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(Canventianal reference system is IF-2)

Type of incentives given

Levelized cost of sabr ene~ No Full

at ‘cansefvatbn’ energ~ incentives 20% ITC incentives

$/MMBN Ptitiw fid..,... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.23 (3.75) 1.88 (3.45) 1.08

t/kWh etici~......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.63 (4.41)

(2.45)

2.21 (4.05) 1.27 (2.88)

Escabtian af conventiacsal ● nergy casts

Canstant real Energy price Energy price

Levelized@ce paid far convenhbnale~~e energy prices escabticm I escabtian II

$/MmBfu primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.72 4.68 8.60

6/kWh eUi~.........................................,.... 4.38 5.51 10.12
Table IV.42.—Albuquerque: Solar Photovoltaic System —Insulated Single Family House Using Plastic Dye Photovoltaic Concentrator

With Passive Cooling; Building Equipped With IF-2 Space-Conditioning

El==

t I

r 1

-w

1 J

ITEMIZED COST OF COMPONENTS

Unit First cost

Component

Annual Life

Size cost (incl. O&P) O&M [yrs.)

1. Electric heat Wimp. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.3 tons 800 $/ton $1,040 $50 10

2. Ductwork . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 425 0 30

3. Electric water hooter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 gals 225 ea. 225 0 15

5. Nontrocking 100x pktic concentrator with 30% 39 m’ 103 $/m’

{

. 2,010 0 30

effkient cells. . 2,010 0 15

—Ptex”~lass and dyes @ 45 $/m*

—Cefls @ 15 S/ms

—-Shipping @ 2 $/CTIZ

——lnstollation @ 20 $/m*

—25% overhead and profit

7. Power conditioning . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.1 53 $/kw 690 4 30

& Lightning wot=tion... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . — — 300 0 30

9. Extra insulation, storm ~and windows., . . . . . . . . . . . . . . . . . . . . . — — 981 0 30

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .........,.........$. . . . . .

$11,381 $54

“ 1, installed cOllectOr cOst assumed rePlaced In t 5 Yrs with total replacement In 30 yrs

ANNUAL ENERGY FLOWS

[Conventional reference system is IF-2)

Energy COCIW1’10d Backup COtlWmOd W/ Enetwy sawd

by ref. tyitem sOlor/conservation (% of total)

Net Electricity (bought-sold) [MWh/unit)..... . . . . . . . . . . . . . . 28.0 2.8 90.0

Fuel corwumed onsite (MMBtu/unit)... . . . . . . . . . . . . . . . . . . . . . . . o. 0.

Totol energy requirement (bbl crude equiv.~ . . . . . . . . . . . . 6s. 7. 90%

Electricity sold to grid annuolly (MWh,entire biting) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14.4

AINIUOl peak electricity demond (kW, sntire biMiW)........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19.0

\———.——/ -— Heat Pump

Compressor

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b’

c

[Ccm.entiowd refere~e system is IF-2]

Escolcstion of conventional energy costs

Constant red Energy price Energy price

● nemv nrices mcalation I escalation II

1. 1976 StortuP

0. Costs using sob (cormewation) system:

Totol with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 133. (170.)

lotcd with 20% ITC............ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125. (163.)

Toted with fu~l incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 106. (140.)

b. Cosb using conventional mfemnce system . . . . . . . . 142.

2. 1985 stOrtcJpd

a. Costs using wbr (conswvation) aystem:

(capitol rdoted Cants . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8J: (118.)

(operotion & mointenonc ● costs) . . . . . . . . . . . . . . . . . . . . . . . (8.)

(fuel bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o. (o.)

(electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 44. (44.)

Totol with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 133. (170.)

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125. (163.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 106. (140.)

144. (181.) 190. (227.)

136. (174.) 182. (220.)

118.,6(151.) 164.27\198.)

8A: (1 18.) 84: (118.)

(8.) (8.)

(0.)

6!: (61.) 13!: (14::/

150. (187.) 222. (259.)

142. (181.) 214. (252.)

124. [158.) 196. (230.)

b. Costs usihg ccmvwrtionoi mfemnce system . . . . . . . . 142. ‘ 183. ‘ 350 .

Ca EFFECTIVE COST OF ENERGY TO CONSUMER

[convemtiomal refemnco system is IF-2)

Typa of incentives given

Levelized cost of $oJor energy No Full

or “conmwation” ● ner# incentives 20% ITC incentives

$/MMBtU primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.00 (3.50) 1.68 (3.23) .94 (2.30)

C/kWh &tii~.......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2.36 (4.12) 1.98 (3.80) 110 (2 7 1 )

Escolotion of conventional energy co~ts

Comtont rd Energy price Energy price

ledixdprice poid for conventi~l ened” energy prices escalation I escalation II

$/mMBtu@nc7v fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.72 4.d8 8.60

C/kWfI Actiily........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.38 5.51 10.12
Table IV-43.—Albuquerque: Solar Photovoltaic System— Insulated Single Family House Using Flat-Plate Air-Cooled Silicon Arrays

($O.SO/Watt), Low-Temperature Thermal Storage; Building Equipped With Improved IF-2 Space-Conditioning

I I 1 1 I

I J %-HkPr> r

I

I

I

I

I

I

I

I

I

I

I

I

I

I

I -. ‘ !Nllng

Heat Engine

WL.-------------------IJ2-I

A. ITEMIZED COST OF COMPONENTS B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollars)b

’

c

(Cc+wentianol reference system is IF-2)

Unit First cost

Conspanent

Annual life

Size cost (incl. O&P) 06M (y~) Escokstian of canventianal energy costs

1. Heot pump . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

2. Ductwark . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3. Electric hat water . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4. Air-caabd silican PV (500 $/kWJ (q = 0.12) . . . . . . . . . . . . . . . .

—Silicon array @ 60 $/ma

——Shipping @ 2 $/ma

—-Installation @ 8 $/m’

——25% o.wheosk and profit

5. POw*r cOditimi~...... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

6. lightning ~t~tti... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

7. Backup engine ond generotar. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

8. Hwt OXti~f......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

9. Law tempemtwe sty............ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

10. Extra insulation, starm dears and windows . . . . . . . . . . . . . . . . . . . . .

1.3 tom

—

40 gal

59 ma

800 $hsl

S22YW.

88 $/m*

$1,040

425

m 10

0 30

0 15

0 30

0 15

Canstont rwl Energy price Energy price

energy prices escobtissn I escobtian II

225

‘2,600

“2,600

1. 1976 Startup

a. Costs using sobr (cansewatian) system:

Totol with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20Y. IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Costs using canwntionol mfemxe system . . . . . . . .

2. 1985 &OrtUP4

a. costs using solar (Cansowatian) system:

(capitol related costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

(afsemfi~ 6 mainbnarsce costs) . . . . . . . . . . . . . . . . . . . . . . .

(fuel bilo . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

(electric billl . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with na incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

b. Cosis using coswenticmol #emnce system . . . . . . . .

159. (21 1.)

146. (2m.)

129. (164.)

142.

171. [224.)

159. [213.)

142. (177.)

168.

183. (235.)

170. (224.)

154. (188.)

7 kW 276.

6.5;kW

114

—

225 $[kW

33 ea.

2 $/kW%

—

800

300

1,470

33

100

981

8 30

0 30

53 10

0 30

0 30

0 30

124. (176.)

16. [16.)

19. (19.)

o. (0.)

159. (21 1.)

146. {200.)

129. (164.)

142.

124. (176.)

(16.)

:;: (38.)

o. [0.)

178. [231.)

166. (220.)

149. [184.)

183.

124. (176.)

16. [16.)

57. (57.)

o. (o.)

197. (249.)

184. [238.)

167. (202.)

330.

50 kWh

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $10,574 $111

C. EFFECTIVE COST OF ENERGY TO CONSUMER

(COSWSSfiOIIOl mferemce system is IF-2)

● % installed cafiector cost assumed replaced in 15 yin., with total replacement in 30 yrs. Typo of incentives given

ANNUAL ENERGY FLOWS Levelized cost of sabr energy No Full

at ‘cansewatian’ energ~ incentives 20% ITC incentives

$/MMBtSJ XWY fad.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.94 (7.52) 4.32 [6.98) 3.49 (5.20)

C/kWh ektici~........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5.82 (8.85) 5.08 (8.22) 4.11 (6.12)

ICanventianal reference system is IF-2)

Energy COSSSUtSlOd Backup CCUSSCStSlOd W/ Energy saved

by ref. SyStOM sabr/cansematian (% of tatol)

Net Electricity (baught-safd) (MWh/unit)..... . . . . . . . . . . . . . . 28.0 100.0

Fuel consumed ansite [MMBtu/unit)... . . . . . . . . . . . . . . . . . . . . . . . 8!: o.

Tatal energy requirement (bbl crude ~uiv.p . . . . . . . . . . . . 2: 18. 73.9

Electricity said ta grid annually (MWh,entim kildiW)........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.

Annual peak electricity demond (kW, entire kiMiW)......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0.

Escabtiw of canventianal energy cash

Canstont real Energy price Energy price

Levelizedpike poid for can.entianal ensw#.* ● nergy prices eecabtian I escabtian II

$/MhfBfcl prinsca~ m.... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.72 4.68 8.60 t/k M ktii~.......... .................................... 4.38 5.51 10.12
Table [V.44.—Aibuquerque: Conventional System— All Electric Single Family House Using Electric Resistance Heat and Window A/C (SF-3)

W,,,?r Eltltrlc tiw

%,pply WA + 1 ,>ac

+ Heater

7- 075

A. ITEMIZED COST OF COMPONENTS

Unit First cost Annual Lif .

Cmllpc.rrent Size cost (inci. O&P) O&M (Yin )

1. Ba\ebwrd electrlc kt............. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.1 67 $/kW $878 30

2. Window electric a/c.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 ~~ 280 S/ton 518 $3: 10

3. Electric woter hooter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 gal $225 eo. 225 0 15

TOTAL.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $1,621 $30

ANNUAL ENERGY FLOWS

(Conventional reference systecn is SF-3)

Energy consumed Backup consumed W/ Energy ~VOd

by ref. system sOkOr/cOrcsemOtiOn (% of tOtoiJ

Net Electricity (bcwght-#1 (Mwh/unit). . . . . . . . . . . . . . . . . . . 43.8 43.8 0.

FwI consumed onsite ltAMBW/nit).... . . . . . . . . . . . . . . . . . . . . . . o. 0. 0.

Total ● nergy requirement (~ ~equiv.p . . . . . . . . . . . . 107. 107. 0.

Electricity sold to grid %w~ IMwh,entim kitiW)......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Annual peak electricity ~(kW, ~fim ~i~iW)......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27!

K—” ———

u=–———”——

B. LEVELIZED MONTHLY COSTS PER UNIT TO CONSUMER (Dollo~)b’c

(Conventional reference system is SF-3)

EKolotiwI of conventional energy costs

J Constant real Energy price Energy price

energy prices e9calati0n I exolation II

1.

2.

.

1976 Stortc#P

Total with no incentive~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 177. [1B5.) 216. [224.) 378. [386.)

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 177. [185.) 216. (224.) 378. (386.)

Total with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 177. [185.) 216. (224.) 378. [386.)

1985 stortup~

ICopitol relclted costs) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19.

(opemtion & maintenance costs) . . . . . . . . . . . . . . . . . . . . . . . 4.

(fuel biHJ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o.

[electric bill) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 153.

Total with no incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 177,

Total with 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 177,

Total with full incentive . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 177.

[27.) 19. [27.) 19. [27.)

(4.) 4. [4.) 4. (4.)

(o.) o. (0.) [0.)

(153.) 215. [215.) 46;: (467.)

[185.) 239. (246.) 490. [498.)

[185.) 239. [246.) 490. (498.)

(185.) 239. (246.) 490. (498.)

C EFFECTIVE COST OF ENERGY TO CONSUMER

(Conventional reference system is SF-3)

Type of incentives given

Lavelized cost of solar energy No Fufl

or ‘consewatiocr’ energ# incentives 20% ITC incentives

$/MMBtu primary fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. N/A [N/A) N/A (N/A) N/A (N/A)

t/kWh electricity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . N / A (N/A) N / A (N/A) N / A (N/A)

Escalation of conventional energy costs

Constant real Energy price Energy price

L.velzedprb poid fcw mwwanticmol ener#,” energy prices exolotion I escolatlon II

$/MhfBw priq fad.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3.57 4.49 8.25

C/kWh tii~........... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.20 5.29 9.72
Table IV.45.—Albuquerque: Conventional System—Ail Electric Single Family l-louse Using Electric Resistance Heat and Window NC,

65/85 Thermosta{Settings (SF-3)

c1

A,, OuCtS

tleat Excn.mger8 Baseboard

+ Electr,c

Heaters

A

Coollng

Load

3

Heating

Load

Waler Elec!r!c

supply

HkV

tlw * Load

+ HeaTer

n = 075

A ITEMIZED COST OF COMPONENTS

Unit First cost Anrrwl Lif e

c~t Sizo coot (incl. O&P) 06M (yre)

1. BOadbamd OhctriC bt............. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.1 67 $/kW $878 30

2. Wlrcdow dbctric a/c.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1.85 tons 280 $/ton 518 $3: 10

3. Electric WOtW heater . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4offcrl $225 eo. 225 0 15

TOTAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $1,621 S30

ANNUAL ENERGY FLOWS

(Ccmv.tiorml refdmnc e system is SF-3)

Ermrgy COrlti Bccckup consumed w/ Em doved

b mf. sY1tenr 9okor/cOrrdervotiOcl [% cd totoll

N.t Ekticity (~t.~ (MWh/unit)..... . . . . . . . . . . . . . . 43.8 42.0 4.2

Fu.1 consumed orwite (MMBtu/unit)... . . . . . . . . . . . . . . . . . . . . . . . o. 0.

Totol energy requiremon t (bki*~ti.r . . . . . . . . . . . . 107. 10!: 4.2

Electricity add to grid omwdfy (MWh,wrtire hiMiW)......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Annuoi p.ak dectricity demond (kW, .ntim biMi~.......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27!

l-m

\

B. LEVEUZED MONTNLY COSTS FER UNIT TO CONSUMER (Dollars)b”c

(COrlventiorml refererrce system is SF-3)

Escdatbn Of C&WdlltiOld ~COStS

constant mol Energy price Erwrgy price

drWluY *OS .scabtiom I McObtbrl II

1. 1976 startup

0. Costs using solar [conservation) syst.rn:

Total with no hcentivos . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 171. (179.) 209. (217.) 364. (372.)

Total with 20% ITC......,..... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 171. (179.) 209. (217.) 364. (372.)

Total with full inc.ntivet . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 171. (179.) 209.

b. Costs using conwntiorroimbmnm systmn........

(217.) 364.~78 (372.) In. 216.

2. 1985 Stortlcpd

a. COstd uding solar (Corra.rvotion) syst.rrr:

(capitol mbtod Costa) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19. [27.) 19.

(oP.Mti 6 mointenqfrce cosh) . . . . . . . . . . . . . . . . . . . . . . .

(27.) 19. (27.)

4. (4.) 4. (4.) 4. (4.)

[W bifl) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . o. (0.) o. (o.) o. (o.)

(Actric &~... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 147. [147.) 207. (207.) 449.

Total with no incentives

(449.)

. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 171. (179.) 230. (238.) 472.

Total With 20% IT... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 171. (179.]

[480.)

230. (238.) 472.

Totol with full incentives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 171. (179.)

(480.)

230. (238.) 472.

b. Costs using conwvnliorrolmbmna sptwr........ IZZ

(480.)

239. 4m.

~ EFFECTIVE COST OF ENERGY TO CONSUMER

Conventional mfemnce system is SF-3)

Type of incentives giVerI

Le.elized cost of +~ No Full

or “Conddrvatbn’ ermrg# incdrrtives 20% ITC incentives

$/MM6tu W- m.... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . -.00 [4.36) -.00 (4.36) -.00 (4.36)

C/kWh &tici~......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . -.00 (5.13) -.W (5.13) -.00 (5.13)

Esabtion of ccwwdIItiOd - codta

constant red EneruY price Energy price

levO/izd* paid for cvrrwntiornderIu#” energy prices escobtiorr I esccrbtion II

$/MMh primary AwL..............,..........,........... 3.57 4 4 9 8.25

~/kWh ktiiW.......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.20 5.29 9.72

1
Note:

From this point onward, this report consists of approximately 500 pages of

tables in very small fonts that were unsuitable for conversion using

optical character recognition. The pages may be posted to the version of

the report stored on the OTA websites, but they will inevitably contain

many recognition errors, and users that wish to consult these tables

should consider obtaining a paper or microfilm copy through NTIS or

through a library.