Cost-benefit analysis of a Building Integrated ... · Cost-benefit analysis of a Building Integrated Photovoltaic Roofing system for a school located in Blacksburg, Virginia Leena

Cost-benefit analysis of a Building Integrated Photovoltaic Roofing

system for a school located in Blacksburg, Virginia

by

Leena Cholakkal

Thesis submitted to the faculty of the Virginia Polytechnic Institute and State University

in partial fulfillment of the requirements for the degree of

Master of Science

in

Architecture

Dr. James Jones, Committee Chair

Prof. Robert P. Schubert

Dr. Virgilio A. Centeno

May 9, 2006

Blacksburg, Virginia

Keywords: Building integrated photovoltaic, roofing system, school, simple payback time

Cost-benefit analysis of a Building Integrated Photovoltaic Roofing system

for a school located in Blacksburg, Virginia

Leena Cholakkal

(Abstract)

In the past few years, there has been a growing concern for the impact of non-renewable

resource depletion and environmental degradation as a result of energy consumption in

buildings. Buildings account for approximately one-half of the total energy consumption

in developed countries. As architects and engineers involved with the fast growing

building industry, we have the responsibility of exploring and integrating various

renewable energy sources into our buildings to help us move towards what we might call

“Positive Energy Architecture”, where the role of the building shifts from net energy

consumer to net energy producer.

The object of this study is to analyze how different parameters namely solar radiation,

temperature, solar altitude and solar azimuth affect the power produced by a new thin

film photovoltaic panel. Through the application of multiple linear regression, the model

developed is then used to evaluate the cost-effectiveness of the building integrated

photovoltaic roofing system when connected to the utility grid when compared to a

conventional roofing system. The analysis is applied to a school building located in

Blacksburg, Virginia. Using the current utility rates and the energy consumption data, the

payback period of the system is evaluated for full roof, half roof and quarter roof

coverage.

iii

Acknowledgments

I would like to sincerely thank my advisor, Prof. Jim Jones for his continuous support and

guidance in directing my thoughts into a well defined study. I also thank him for

providing the necessary equipment and software to conduct the research and directing my

graduate study throughout the course of my stay here.

I would like to thank Prof. Schubert for his valuable suggestions and comments

throughout the course of the research especially with the cost analysis of the system.

I would like to express my sincere gratitude to Dr. Centeno from the department of

Electrical and Computer engineering at Virginia Tech for all the help with the circuits

and for taking time from his busy schedule to visit the research facility to check the

experimental setup. Thank you very much for all the help and support.

I extend my sincere gratitude to Mr. Ed Miller from Montgomery County Public Schools

for providing me the necessary data for the study.

Special thanks to Ying Zhang from the Statistical Consulting Center at Virginia Tech for

her help with developing the regression models using the Statistical software.

Thanks to Ross, Anchi and Manoj for being there to help me out with the setup at the

Research and Development facility. Special thanks to Ross for all the help with the

circuit wiring on the roof and setting up the data logger. I would not have been able to do

it without him.

I would also like to thank all my friends especially Alfred, Veena, Aseem, Khushboo,

Aniruddh and Emran for making my stay in Blacksburg a wonderful experience. Special

thanks to my room mate Kalpana for her patience with me during all those busy times of

research work.

iv

I am extremely grateful to my family especially my parents for their belief and faith in

me. Thank you for giving me the freedom to explore and learn. Thanks to my brother,

Santosh and my sister, Smitha for being wonderful friends and encouraging me to reach

higher. This work is dedicated to my family.

v

Table of Contents

Abstract ii

Acknowledgements iii

Table of Contents v

List of Figures vii

List of Equations ix

List of Tables x

Chapter 1: Introduction 1

1.1 Introduction 1

1.2 Goal and Objectives 2

1.3 Assumptions 3

1.4 Hypothesis 3

1.5 Research Approach Summary 4

Chapter 2: Literature Review 5

2.1 Photovoltaic: Principles and advantages 5

2.1.1 Solar energy to electricity 5

2.1.2 Advantages 6

2.1.3 Photovoltaic systems 6

2.1.4 Applications 8

2.2 Building Integrated Photovoltaic 10

2.2.1 Introduction 10

2.2.2 BIPV interfaced with the utility grid 10

2.2.3 Power production of BIPV 11

2.3 Examples of BIPV in buildings 11

2.4 Application of literature review to research approach 13

Chapter 3: Methodology 14

3.1 The Photovoltaic system 14

3.2 The Circuit Setup 15

3.3 The Experimental Setup 18

3.4 Parameters for the study 19

3.4.1 Solar Radiation 19

vi

3.4.2 Temperature 21

3.4.3 Solar Azimuth and Solar Altitude 23

3.4.4 Voltage and current 26

3.5 Data Acquisition System 27

3.6 Data Logging Software and data collection 30

3.7 Model for study in Phase 2 31

3.8 Summary for methodology 32

Chapter 4: Results 33

4.1 Relationship between power and the independent variables 33

4.2 Multiple Linear Regression Analysis 34

4.3 Regression Model using Statview 35

4.4 Cost analysis case study 38

4.5 Simple Payback Analysis 38

4.6 Simple Payback Time Calculator 39

4.6.1 Energy Consumption data 39

4.6.2 Load Profile for typical school day 40

4.6.3 Electricity production prediction using the regression model 45

4.6.4 Electricity production for different roof areas 45

4.6.5 Simple Payback time 52

4.6.6 Simple payback time for different utility rates and rebates 53

4.6.7 Simple payback time for different utility rates and demand charge 55

4.7 Summary of Results 57

Chapter 5: Conclusions and Discussion 58

5.1 Conclusions 58

5.2 Limitations of the study and recommendations 58

References 60

Appendix A: Regression Analysis 62

Appendix B: Electricity production 63

B.1 Electricity production in each month using the Regression Model 63

B.2 Electricity production and utility bill calculation 70

vii

List of figures

Fig 2.1 - Solar cell operating principles 5

Fig 2.2 - Mono-crystalline silicon cell 7

Fig 2.3 - Poly-crystalline silicon cell 7

Fig 2.4 - Amorphous silicon cell 8

Fig 2.5 - Grid connected PV installation 10

Fig 2.6 - Brundtland centre 11

Fig 2.7 - Rooftop PV array 12

Fig 2.8 – Student Housing, Switzerland 12

Fig 3.1 – Layout of panels on the roof 16

Fig 3.2 - Schematic diagram for the red circuit 17

Fig 3.3 – Schematic diagram for the white circuit 17

Fig 3.4 – Schematic diagram for the blue circuit 18

Fig 3.5 – Layout of the PV panels on the roof 18

Fig 3.6 – Wiring on the roof 19

Fig 3.7 – LICOR sensor measuring solar radiation 20

Fig 3.8 – Production efficiency for different PV panel temperatures 21

Fig 3.9 – Thermal sensor (Copper-constantan thermocouple) 22

Fig 3.10 – Layout of thermal sensors 22

Fig 3.11 - Input window for Altitude /Azimuth calculator 24

Fig 3.12 – DC light bulbs used as load 27

Fig 3.13 – SCXI Chassis with the modules and terminal blocks 28

Fig 3.14 – SCXI-1303 Terminal block 29

Fig 3.15 – SCXI-1327 Terminal Block 29

Fig 3.16 - Snapshot of VirtualBench – Logger 30

Fig 4.1 – Power per unit area, for different solar radiations 33

Fig 4.2 – Power per unit area, for different altitudes 33

Fig 4.3 – Power per unit area, for different temperatures 34

Fig 4.4 – Sample output of Regression Analysis from Statview 36

Fig 4.5 – Final Output of Regression Analysis from Statview 37

Fig 4.6 – Kipps Elementary School 38

viii

Fig 4.7 – Load profile for a typical school day 40

Fig 4.8 – Electricity Load Profile for typical day in January 41

Fig 4.9 – Electricity Load Profile for typical day in February 41

Fig 4.10 – Electricity Load Profile for typical day in March 42

Fig 4.11 – Electricity Load Profile for typical day in April 42

Fig 4.12 – Electricity Load Profile for typical day in May 42

Fig 4.13 – Electricity Load Profile for typical day in June 43

Fig 4.14 – Electricity Load Profile for typical day in July 43

Fig 4.15 – Electricity Load Profile for typical day in August 43

Fig 4.16 – Electricity Load Profile for typical day in September 44

Fig 4.17 – Electricity Load Profile for typical day in October 44

Fig 4.18 – Electricity Load Profile for typical day in November 44

Fig 4.19 – Electricity Load Profile for typical day in December 45

Fig 4.20 – Electricity chart for January 46

Fig 4.21 – Electricity chart for February 46

Fig 4.22 – Electricity chart for March 47

Fig 4.23 – Electricity chart for April 47

Fig 4.24 – Electricity chart for May 48

Fig 4.25 – Electricity chart for June 48

Fig 4.26 – Electricity chart for July 49

Fig 4.27 – Electricity chart for August 49

Fig 4.28 – Electricity chart for September 50

Fig 4.29 – Electricity chart for October 50

Fig 4.30 – Electricity chart for November 51

Fig 4.31 – Electricity chart for December 51

ix

List of Equations

Equation 1.1 - Hypothesis relating power to the independent variables 3

Equation 3.1 – Solar Altitude related to declination, latitude and hour angle 25

Equation 3.2 – Solar Altitude in radians 25

Equation 3.3 – Trigonometry formula 25

Equation 3.4 – Trigonometry formula 25

Equation 3.5 – Calculation of Solar Altitude 25

Equation 3.6 – Calculation of Azimuth 26

Equation 3.7 – Calculation of power 31

Equation 4.1 - Hypothesis relating power to the independent variables 35

Equation 4.2 – Regression Model developed 38

Equation 4.3 – Simple Payback Time Calculation 39

x

List of Tables

Table 3.1 – Color coding for the thermal sensors 23

Table 3.2 - Sample format for the data collected 31

Table 4.1 – Energy consumption data for Kipps Elementary School, year 2005 40

Table 4.2 – Electricity bills for different roof coverage 52

Table 4.3 – Savings for different roof coverage 53

Table 4.4 – Simple Payback period for full roof coverage 54

Table 4.5 – Simple Payback period for half roof coverage 54

Table 4.6 – Simple Payback period for quarter roof coverage 55

Table 4.7 – Simple payback period for Utility rate = $0.08/kWh 55







1

Chapter 1: Introduction

1.1 Introduction

In the United States, buildings and their processes for heating, cooling and functional use,

account for approximately one-half of all energy consumption. Architects and engineers

associated with the fast growing building industry have the responsibility of exploring

and trying to integrate various renewable sources of energy in the early stages of the

building design. With this approach we might achieve “Positive Energy Architecture”

where the role of the building shifts from a net energy consumer to a net energy producer.

One of the most promising renewable energy technologies is photovoltaic (PV) power.

PV systems are truly elegant means of producing on-site electricity from the sun without

noise, pollution or any moving parts. It is estimated that one hour of solar energy

received by the earth is equal to the total amount of energy consumed by humans in one

year. By harnessing this renewable source we might reduce our dependence on non-

renewable energy sources.

One appealing aspect of photovoltaic power is that by producing electricity at the

building site, the distribution becomes distributed thereby shifting power generation away

from a regionally located central source. Grid-connected, distributed power systems are

gaining popularity and this trend is expected to continue making it a common feature of

future buildings.

Some of the advantages of building integrated photovoltaic (BiPV) distributed systems

are as follows:

• Serve as both the building envelope material and the power generator

• Provide savings in materials and electricity costs

• Reduce use of fossil fuels

• Add architectural interest to the building.

• Reduces the cost and losses in transmission and distribution of electricity

2

• Can help reduce peak loads and utility demand

• No site development cost, BIPV is part of the building

• BIPV system provide public expression of environmental commitment

• The system is carbon dioxide neutral once it is paid back

Million Solar Roofs Initiative:

The U.S. Department of Energy Million Solar Roofs initiative is a public-private

partnership which aims to increase the market entry of solar technologies. The goal is “ to

facilitate use of the sun's energy to reduce our reliance on fossil fuels by installing solar

panels on 1,000,000 more roofs around our nation by 2010”. 1

The awareness of the benefits of PVs is rapidly increasing but cost and technical issues

remain for design and installation that have slowed acceptance and application of these

systems. This study aims to provide an understanding of what factors affect the

performance of BIPV and to formulate a model which can be applied to predict the

performance of the BIPV in a building and thereby give insight as to if the system could

be cost effective.

1.2 Goal and objectives

Goal:

The main goal of the study is to create awareness about the economic feasibility of

building integrated photovoltaic roofing over conventional non-power generating

systems, while considering the performance over the life of the system.

Objective:

• To evaluate the cost-effectiveness of a building integrated photovoltaic roofing

system over that of a conventional roofing system in a school building located in

1 www.millionsolarroofs.org, U.S. Department of Energy, Energy Efficiency and Renewable Energy, Solar Energy Technologies Program

3

Blacksburg, Virginia while considering the influential parameters including solar

radiation, solar altitude, solar azimuth, temperature and utility rates in that region.

1.3 Assumptions

• Life of the building integrated photovoltaic is assumed to be 25 years2

• The building integrated photovoltaic is connected in parallel to the utility grid, so

there is no cost for batteries or electrical storage.

• The model developed for calculating power using the experimental setup in

Blacksburg is suitable for application in other areas for future studies.

• The calculations are based on TMY (Typical Meteorological Year) files and done

for a typical school day. Limitations of the model and scope for future

improvement are discussed in Chapter 5.

1.4 Hypothesis

The research hypothesis establishes the relationship between power generated per unit

area by the PV system and other parameters including solar radiation, solar azimuth, solar

altitude and temperature. The hypothetical model is shown in Equation 1.

P = bo + b1(Sol. Rad) + b2(Sol. Az) + b3 (Sol. Alt) – b4(Temp) Equation 1.1

Where

P = Power generated in watts per square meter

Sol. Rad = Solar radiation incident upon the panels at any particular time in watts per square meter

Sol. Az = Solar azimuth based on the location and season (degree)

Sol. Alt = Solar altitude based on the time of the day (degree)

Temp = Temperature of the panel in degree Fahrenheit

2Energy and economic evaluation of building-integrated photovoltaic by M. Oliver and T. Jackson;

Centre for Environmental Strategy, University of Surrey, Guildford, Surrey GU2 7XH, UK

4

Considering the life of the BIPV and the high utility rates and rebates, it is further

hypothesized that over the life of the systems:

Cost (conventional roofing) > Cost (BIPV)

The cost analysis is for a school because of the large roof area available for the

installation of the building integrated roofing system, the time of peak demand and peak

production match and the need to limit present and future energy cost expenditures for

public-sector buildings.

1.5 Research Approach Summary

Chapter 1 introduced the need for the study to develop a model which will give quick

insight into the economic feasibility of the system for any building project and provide a

description of the goals and objectives, assumptions and hypotheses for this study. In

order to formulate the study and focus on the key issues it is necessary to begin with the

background knowledge of BIPV. This summary is found in Chapter 2: Literature Review.

The experimental setup and the procedures used for collecting the data are described in

Chapter 3: Methodology. Chapter 4 summarizes the results. Chapter 5 provides

discussion and conclusions drawn from the results and suggests how the Government

might advance the use of BIPV by providing rebates and incentives. It also discusses the

limitations of the model and the possible further studies.

5

Chapter 2: Literature Review

2.1 Photovoltaic: Principles and advantages

2.1.1 Solar energy to electricity

Photovoltaic cells, commonly known as solar cells, are converters; they take energy from

sunlight and convert it into electricity without any moving parts, noise or pollution. This

is possible through the special properties of the semi-conducting materials that the cells

are made.

Fig 2.1 – Solar cell operating principles3

Most PV cells are made from silicon. Silicon is a "semi-conductor" and has properties of

both a metal and an insulator. Atoms in a metal have loosely bound electrons that easily

flow when electrical pressure is applied, whereas atoms in an insulator have tightly bound

electrons that cannot flow when electric voltage is applied. Atoms in a semi-conducting

material bind their electrons tighter than metals, but they may be manipulated to have

conductive properties.

PV cells are made by joining two types of semi-conducting material: P-type and N-type.

P-type semi-conductors are manufactured to contain negative ions, and N-type semi-

conductors are manufactured to contain positive ions. The positive and negative ions

3 (Figure 3, page 23) Deo Prasad and Mark Snow, Designing with solar power – A source book for Building Integrated Photovoltaics (BiPV)

6

within the semiconductor provide the environment necessary for an electrical current to

move through a solar cell.

At the atomic level, light is made of a stream of pure energy particles, called "photons."

This pure energy flows from the sun and shines on the solar cell. The photons actually

penetrate into the silicon and randomly strike silicon atoms. When a photon strikes a

silicon atom, it ionizes the atom, giving all its energy to an outer electron and allowing

the outer electron to break free of the atom. It is the movement of electrons with energy

that we call "electric current." The power produced by the photovoltaic is direct current

(DC) power which is converted to AC power using an inverter.4

2.1.2 Advantages

Photovoltaics were first used commercially in 1958 to power the Vanguard

communications satellite. As a result of declining prices, the practical application for PVs

has steadily expanded to include the building industry. PVs can be applied to reduce the

peak electrical load and offer the possibility of the building becoming a net energy

producer.5

Solar electric power offers multiple benefits when compared to conventional power

systems including:

• Reliable and low maintenance

• Modular and scalable

• Zero emissions

• Renewable

• No fuel or infrastructure

2.1.3 Photovoltaic systems

There are basically two categories of photovoltaic systems with several types in each

category.

4 Solar integrated technologies 5 Powerlight Solar Electric Systems

7

Crystalline Silicon PV systems:

Crystalline PV systems include monocrystalline and polycrystalline silicon which are

grown or cast from molten silicon and later sliced into individual “cells”. They are then

sandwiched between glass plates and framed with aluminum to form a rigid panel.

Monocrystalline photovoltaic:

This is the oldest and most expensive production technique, but it is also the most

efficient sunlight conversion technology commercially available. The output efficiencies

average between 10 to 12%. Boules of pure single-crystal silicon are grown in an oven,

then sliced into wafers, doped and assembled.

Fig 2.2 – Monocrystalline silicon cell6

Polycrystalline photovoltaic:

In this technique, pure molten silicon is cast into cylinders and then sliced into wafers. It

is slightly lower in efficiency when compared to monocrystalline PV, but the cost is also

lower. Module efficiency averages about 10 to 11%.

Fig 2.3 – Poly-crystalline silicon cell7

6 (Figure 4, page 23) Deo Prasad and Mark Snow, Designing with solar power – A source book for Building Integrated Photovoltaics (BiPV)

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Flexible PV systems:

Flexible photovoltaic systems are produced in vacuum plasma ovens which deposit a thin

layer of silicon material onto a flexible polymer or steel substrate. This technology is

commonly known as amorphous silicon thin film. Advantage of this PV technology is

that its lightweight and its flexible properties facilitate the integration of the cells into

traditional building products and systems such as roofs, facades or windows. The

conversion efficiency averages about 5 to 7%.

Fig 2.4 – Amorphous Silicon cell8

2.1.4 Applications

Solar generated electricity can serve people living in most isolated areas as well as in the

center of densely populated cities. The applications are many as listed below:

Simple PV systems

These systems use the DC electricity as soon as it is generated to power water pumps for

irrigation and drinking wells, and ventilation fans for air cooling. They are small systems

typically less than 500 watt and weigh less than 150 pounds, which makes them easy to

transport and install.

7 (Figure 5, page 23) Deo Prasad and Mark Snow, Designing with solar power – A source book for Building Integrated Photovoltaics (BiPV) 8 (Figure 9, page 25) Deo Prasad and Mark Snow, Designing with solar power – A source book for Building Integrated Photovoltaics (BiPV)

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PV with battery storage

When coupled with battery storage, PV systems become reliable sources of electric

power day and night and when used with an inverter, they can be designed to power DC

or AC equipment.

PV with Generators

When power must always be available or when larger amounts than the PV system alone

can supply are needed, an electric generator can work effectively with the PV system to

supply the needed electricity. If batteries run low, the generator makes up for the

difference in electrical demand.

Grid connected PV

Where utility power is available, a grid-connected PV system can supply part of the

energy needed. Referred to as a part or partial load systems, this approach typically does

not include the expensive battery sub-system. The partial load system reduces the peak

electrical demand from the local utility and can be very cost effective in locations with

high purchased utility demand charges such as California.

Utility-Scale Power

Large scale utility photovoltaic power plants, consisting of many PV arrays installed

together are typically easier and quicker to install and connect than conventional power

plants. The PV plants can be incrementally expanded as demand increases and consume

no fuel or produce no pollution as they generate electricity.

Hybrid Power Systems

Hybrid systems combine PV systems with wind turbines or small hydro plants to produce

electricity. These are ideal for remote applications such as communication stations,

military installations and rural villages.

10

2.2 Building integrated photovoltaic

2.2.1 Introduction

Building Integrated Photovoltaic (BIPV) systems consist of integrating photovoltaic

modules into the building envelope. The advantages of BIPV are:

• Serves as the building envelope material and power generator

• Provide savings in material and electricity costs

• Reduces the use of fossil fuels

• Adds architectural interest to the building

2.2.2 BIPV system interfaced with the utility grid

The PV system can be connected in parallel to the utility grid and eliminate the need for

the batteries. There are several advantages in a grid connected system:

• Both the building owner and the utility benefit with grid tied BIPV

• On- site production of electricity is typically greatest at or near the time of a

building’s and utility’s peak loads

• Can reduce energy costs for the building owner

• Exported solar electricity helps support the utility grid during the time of its

greatest demand and helps the facility to reduce peak loads when the utility rates

are highest.

Fig 2.5 - PV connected to utility grid9

9 (Figure 13, page 26) Deo Prasad and Mark Snow, Designing with Solar Power – A source book for Building Integrated Photovoltaic

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2.2.3 Power production of BIPV

The production of the BIPV depends on a number of variables mainly:

• Solar radiation (variation due to the rotation of the earth and movement around

the sun as well as cloud cover)

• Solar altitude (tilt)

• Solar azimuth (orientation with respect to due south)

• Temperature

• Shading or shadow

• Dirt accumulation

• Cell efficiency

The relationship between the variables, namely solar radiation, solar altitude, solar

azimuth and temperature and the power generated per unit area by the BIPV is explored

in detail using data collected from this experimental study.

2.3 Examples of BIPV in buildings

Fig 2.6 through 2.8 shows some examples of Building integrating photovoltaic in

buildings.

Fig 2.6 – Brundtland Centre10

10(Figure 1, page 70) Deo Prasad and Mark Snow, Designing with solar power – A source book for Building Integrated Photovoltaics (BiPV)

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Brundtland Centre

Location : Toftlund, Denmark

Size : 14.25 kWp

PV Type : Roof and façade system

Building type : Commercial

Fig 2.7 – Rooftop PV array11

J-House

Location : Tokyo, Japan

Size : 4.94 kWp

Gross PV Surface Area : 34.2 m2

PV Type : Monocrystalline and polycrystalline silicon cells

Fig 2.8 – Student Housing, Switzerland12

11 (Figure 4, page 98) Deo Prasad and Mark Snow, Designing with solar power – A source book for Building Integrated Photovoltaics (BiPV) 12 (Figure 1, page 147) Deo Prasad and Mark Snow, Designing with solar power – A source book for Building Integrated Photovolatics (BiPV)

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Student Housing, Switzerland

Location : Lausanne, Switzerland

Size : 14.4 kWp

PV Cell Type : Polycrystalline silicon

Type of building integration : Facade

2.4 Application of Literature Review to Research Approach

The literature review provides an understanding of the basic principles, advantages and

the different systems and applications available for PVs. Based of the aesthetics, ease of

installation and cost, BIPV roofing system connected to the utility grid is chosen for the

study. The variables that affect the performance of the PV system were identified for

detailed study using the experimental setup. A review of different papers helps to focus

on this issue which has not been experimentally established in detail. The research

approach and model of study are discussed in detail in Chapter 3: Methodology

The building integrated photovoltaic panel used for the study is discussed in detail in

section 3.1. The utility rates and demand charges are discussed in section 4.6.

14

Chapter 3: Methodology

The study consists of two phases. The first phase involves setting up of the thin film

photovoltaic system on the roof at the Research and Development Facility on the campus

of Virginia Tech. Then data were collected for the electrical power production of the

system. The data collected is used to formulate a model which estimates the relationship

between the power generated per unit area of the panel and the independent variables

namely temperature, solar radiation, solar altitude and azimuth. In the second phase, the

model developed in phase one is applied to Kipps Elementary School building located in

Blacksburg, Virginia to estimate the simple payback time for different areas of roof

coverage and evaluate the cost-benefit of the system.

Development of the experimental setup

3.1 The Photovoltaic system

From the literature review, when considering factors such as cost, flexibility, ease in

handling and integration into the building, the thin film photovoltaic system was chosen

for the study. UNI-SOLAR®, a world leader in thin-film solar technologies with years of

experience in photovoltaic manufacturing, provided 10 panels of Solar Laminate PVL-

series for the study. The panels were connected in combination of parallel and series to

form three different circuits labeled as red, blue and white (color coding for easy

recognition) for the study.

The thin film photovoltaic used for the study is from UNISOLAR and has the

specifications as follows:

Solar Laminate PVL-Series

UniSolar PV laminates (PVL) are flexible and light weight laminates made to be

exceptionally durable by encapsulation of the PV cell in UV stabilized polymers. The

polymer encapsulation is partially constructed of durable ETFE (eg: Tefzel®, a high

light-transmittive polymer). The UniSolar PV cells are produced in a 3-stage spray

deposit process with each layer being sensitive to selected wavelengths of light. With this

15

3-step process, the PV cells are more efficient at both full and partial incident radiation

when compared to similar products.

The UniSolar panels have the following characteristics:

• Thin, light-weight

• Flexible and unbreakable

• Easy to integrate with the roof

• Aesthetically pleasing

• Relatively low installation cost

• High temperature and low light performance

• 20 year warranty on power output at 80%

• Multi-contact connectors or junction box

• Bypass diodes for shadow tolerance

Construction Characteristics

Dimensions: Length: 5486mm (216”), Width: 394mm (15.5”), Depth: 2.5mm (0.1”)

Weight: 7.7kg (17.0 lbs)

Electrical specifications: STC

( at 1000W/m2, AM 1.5, 25°C cell temperature)

Voltage at Pmax (Vmp):40.0V

Current at Pmax (Imp): 4.1A

Short-circuit Current (Isc): 5.1A

3.2 The Circuit Setup

Using the 10 panels donated by UniSolar, three circuits are setup as shown in the figures

3.1 through 3.2. All the panels and combinations are color coded for ease in setting up the

circuits and the data logging device.

16

Fig 3.1 – Layout of panels on the roof

Color coding the circuits

Panels coded white and yellow are connected in parallel to form the red circuit. Panels

coded green and magenta + green are connected in parallel to form the white circuit.

Panels coded magenta + yellow and magenta are connected in parallel to form the blue

circuit. Three different circuits are used to study the effect of connecting the panels in

parallel and in series on the power production.

The schematic circuit diagrams for the different setups are shown in the figures 3.2

through 3.4.

PANEL 2 24-40V 4.13A

PANEL 1 24-40V 4.13A

PANEL 3 24-40V 4.13A

PANEL 4 24-40V 4.13A

PANEL 5 24-40V 4.13A

PANEL 9 24-40V 4.13A

PANEL 10 24-40V 4.13A

PANEL 8 24-40V 4.13A

PANEL 7 24-40V 4.13A

PANEL 6 24-40V 4.13A

YELLOW

MAGENTA + YELLOW

GREEN MAGENTA + GREEN

WHITE MAGENTA

17

Fig 3.2 - Schematic diagram for the red circuit

Fig 3.3 – Schematic diagram for the white circuit

PANEL 1 WHITE

PANEL 2 YELLOW

DATA LOGGER

R

R

R

Shunt = 0.05Ω

R – Sylvania bulb rated at 25w/12v Shunt resistance = 0.005Ω

R

R R

PANEL 4&5 GREEN

PANEL 6&7 MAGENTA+GREEN

R R

R

Shunt = 0.05Ω


R R

R

DATA LOGGER

18

Fig 3.4 – Schematic diagram for the blue circuit

3.3 The Experimental Setup

To simulate the BIPV system, the panels were setup (as shown in Fig 3.5) on

ThermaSteel™ structural insulating panels which were fixed on the flat roof at the

Research and Development Facility. The circuits are setup as shown in Fig 3.2 through

Fig 3.4.

Fig 3.5 – Layout of the PV panels on the roof

PANEL 3&8 MAGENTA+YELLOW

PANEL 9&10 MAGENTA

DATA LOGGER

R R

R

Shunt = 0.05Ω


R R R

R R

R

R R

R

19

Fig 3.6 – Wiring on the roof

3.4 Parameters for the study

From the Equation 1, it was hypothesized that power production (dependent variable)

would be a function of four independent variables, solar radiation, temperature, solar

altitude and azimuth.

3.4.1 Solar radiation

Solar irradiance (solar radiation) is the amount of solar energy that falls on a unit area of

a surface per unit of time. It is measured in watt/m2. From the literature review, solar

radiation is identified as one of the most important parameters affecting the power

production.

For measuring the solar radiation, a glass panel with a wooden frame is setup with

LI-COR pyranometers fixed above and below the glass panel. This helps to observe the

effect of dirt accumulation on the glass as an indirect indicator of dirt accumulation on

the solar panels. The uncovered sensor is used to measure the incident solar radiation.

20

Fig 3.7 – LICOR sensor measuring solar radiation

The sensor used for measuring the solar radiation is a LI-COR Sensor with the

specifications as given below:

Model Number: LI-200SZ

Serial Number: PY32791

Output: 91.6 microamps per 1000 watt m-2

The data for solar radiation is measured in millivolts by the datalogger which is converted

into watt/m2 using the following conversion factor.

Conversion

Output: 91.6 microamps per 1000 watt m-2

91.6 microamps = 1000 watt m-2

91.6 millivolt = 1 watt m-2

1 millivolt = 1/91.6 watt m-2 = 0.10917 watt m-2

1 volt = 109.17 watt m-2

21

3.4.2 Temperature

The dry bulb air temperature is measured with a shielded thermocouple. From the

literature study as shown in Fig 3.8, temperature is identified as a parameter that affects

the power production by photovoltaic.

Fig 3.8 – Production efficiency for different PV panel temperatures13

Thermal sensors:

Seven copper-constantan thermocouples were laid out on top and below the panels to

measure the temperature near the panels. One thermocouple is placed about 6” above the

panel to measure the air temperature. All the thermal sensors are color coded and

connected to the channels (numbered) in the module of the data logger to record the

temperature at one minute intervals throughout the day.

13 Deo Prasad and Mark Snow, Designing with Solar Power – A source book for Building Integrated Photovoltaic

22

Fig 3.9 – Thermal sensor (Copper-constantan thermocouple)

The layout of the thermocouple sensors above and below the panel is shown in Fig 3.9

and Fig 3.10 and Table 3.1 gives the color code for the sensors.

Fig 3.10 – Layout of thermal sensors

PANEL 2 ch4(top)

PANEL 1

PANEL 3 ch2(below)

PANEL 4 ch5(top)

PANEL 5

PANEL 9 ch1(top)

PANEL 10 ch7(below)

PANEL 8 ch3(top)

PANEL 7

PANEL 6

23

Table 3.1 – Color coding for the thermal sensors

Channel number Location Color code

Ch0 Air No color

Ch1 Top Panel 9 Yellow

Ch2 Below Panel 3 Green

Ch3 Top Panel 8 Magenta

Ch4 Top Panel 2 Yellow+ Green

Ch5 Top Panel 4 Magenta

Ch7 Below Panel 10 Green + Yellow + Magenta

3.4.3 Solar Azimuth and Solar Altitude

Solar Azimuth is the angle within the horizontal plane measured from true south

(typically) or north. Solar Altitude is the vertical angle between the horizontal and the

line parallel to the sun’s rays. At sunset/sunrise altitude is 0 and is 90 degrees when the

sun is at the zenith. The altitude relates to the latitude of the site, the declination angle

and the hour angle.

Based on the date and time, the solar azimuth and altitude are calculated using the sun

altitude azimuth table calculator of the day from the Astronomical Applications

Department from US Naval observatory. In the calculator used, true north corresponds to

0 degree.

(Courtesy: http://aa.usno.navy.mil/data/docs/AltAz.html)

24

U.S. Naval Observatory Astronomical Applications Department

Sun or Moon

Altitude/Azimuth

Table for One Day

This page provides a way for you to obtain a table of the altitude and azimuth of the Sun or Moon during a specific day, at a time interval that you specify. Simply specify the object, date, tabular interval, and place below and click on the "Compute Table" button. The altitude and azimuth values are tabulated as a function of the standard time of the place requested (daylight time is not used) on a 24-hour clock.

Use Form A for cities or towns in the U.S. or its territories. Use Form B for all other locations. Both forms are immediately below.

Please read the Notes section for details on the data and definitions of altitude and azimuth.

Form A - U.S. Cities or Towns

Object: Sun Moon

Year: 2006

Month: May

Day: 3 Year:

2004

Month: Day: 1

Tabular Interval: 10 minutes (range 1-120 minutes)

State or Territory: D.C.

Place Name:

Fig 3.11 - Input window for Altitude /Azimuth calculator

25

The place name you enter must be a city or town in the U.S. or its territories. The place's location will be retrieved from a file with over 22,000 places listed. Either upper- or lower-case letters or a combination can be used. Spell out place name prefixes, as in "East Orange", "Fort Lauderdale", "Mount Vernon", etc. The only exception is "St.", which is entered as an abbreviation with a period, as in "St. Louis".

Compute Table Clear all f ields

Alternatively the solar altitude and azimuth can be calculated as described below.

Calculation of Solar Azimuth and Solar Altitude

Solar Altitude:

sin(Alt) = cos(Lat) cos(Decl) cos(HAngle) + sin(Lat) sin(Dec) – Equation 3.1

where

Alt = Altitude (angle degree)

Lat = Latitude (angle degree)

Decl = Declination (angle degree)

HAngle = Hour Angle

sin_alt_r = cos(lat_r)*cos(decl_r)*cos(hour_r)+sin(lat_r)*sin(decl_r) - Equation 3.2

sin2alt = sin_alt_r * sin_alt_r – Equation 3.3

cos_alt_r = sqrt(1 - sin2alt) – Equation 3.4

altitude = atan(sin_alt_r / cos_alt_r) * TODEGREE – Equation 3.5

where:

sin_alt_r = Sine of altitude in radians

lat_r = Latitude in radians

decl_r = Declination in radians

lat_r = Latitude in radians

cos_alt_r = Cosine of altitude in radians

TODEGREE = Constant equal to 180/pi

26

Solar Azimuth:

Alt = Altitude (angle degree)

Azm = Azimuth (angle degree)

Decl = Declination (angle degree)

HAngle = Hour angle (angle degree)

alt_R = Altitude in radians

azm_R = Azimuth in radians

lat_R = Latitude in radians

hour_R = Hour angle in radians

x_azm = x component of azimuth

y_azm = y component of azimuth

TODEGREE = Constant equal to 180/p

sin(Azm) = cos(Decl) sin(HAngle) /cos(Alt) – Equation 3.6

3.4.4 Voltage and current

For the three circuit setups, DC light bulbs and shunt resistors were used as loads to draw

maximum power from the PV circuit. The voltage and current across each circuit was

recorded by the data logger and total power per unit area is calculated.

Details of the voltage module and the data logger are explained in 3.5.

Specifications for the load:

Bulb:

Sylvania 25W/12V

Light Output : 385 lumens

Life : 1000hours

Shunt resistance : 0.05Ω

27

Fig 3.12 – DC light bulbs used as load

3.5 Data Acquisition System

The data acquisition system is an important part of the experimental setup. A good

experiment can be completely ruined if the data is not collected with the necessary

precision and repeatability. The data acquisition system used is described below.

The datalogger used is a National Instruments Signal Conditioning eXtensions for

Instrumentation (SCXI) chassis, modules and associated DAQ devices. SCXI is a high-

performance signal conditioning and instrumentation architecture for measurement and

automation systems. It consists of multi-channel signal conditioning and data acquisition

modules installed in a chassis

SCXI Chassis

The SCXI Chassis used is the SCXI-1001 12-slot chassis. It houses the SCXI modules,

supplying power and controlling the SCXIbus. The rugged aluminum SCXI chassis

contains an analog bus, a digital bus and a chassis controller that regulates bus operation.

The analog bus transfers analog signals from all resident analog modules to the DAQ

device using a connection from one of the modules to the DAQ device.

28

SCXI Modules

The SCXI Module used is the SCXI-1102 which can be used for millivolt, thermocouples

and current inputs. The SCXI-1125 is used to measure voltage produced by the circuit.

The SCXI-1102 is a 32-channel amplifier module for low voltages. The SCXI-1125 is a

jumperless 8-channel amplifier.

SCXI Terminal Blocks

The SCXI-1303 is the terminal block used for collecting data on the current produced, the

temperatures and the solar radiation. Feature: Isothermal, signal referencing and open

thermocouple detection.

The SCXI -1327 is used for collecting data on the voltage produced by the three different

circuits. Features include 100:1 attenuation of voltages to 250 Vrms2, switch configurable

per channel.

Fig 3.13 – SCXI Chassis with the modules and terminal blocks

29

Fig 3.14 – SCXI-1303 Terminal block

Fig 3.15 – SCXI-1327 Terminal Block

30

Sensors

Description of the sensors used for measuring the various parameters has been stated in

Section 3.4 Parameters for the study.

3.6 Datalogging software and data collection

The software used for collecting the data is VirtualBench Version 2.6 for Windows from

National Instruments Corporation. The VirtualBench suite of tools is a high-performance,

easy to use virtual instruments application program for Windows. The VirtualBench-

Logger is used to collect the data by configuring it for temperature, solar radiation,

voltage and current at one minute intervals. The Front panel of the VirtualBench-Logger

displays the data collected at every minute as shown in Fig 3.14.

Fig 3.16 - Snapshot of VirtualBench – Logger

31

Table 3.2 - Sample format for the data

Date Values

Time Values

Air Temp (F) Values

Top Panel 7 (F) Values

Below Panel 3 (F) Values




Below Panel 8 (F) Values

White A (A) Values

Blue A (A) Values

Red A (A) Values

Pyranometer (w/m2) Values

Blue volt (V) Values

White volt (V) Values

Red Volt (V) Values

The power produced by each circuit is calculated using Equation 3.7

Power = Voltage * Current – Equation 3.7

The power per unit area was calculated by dividing by the total area of the panels in the

circuit setup. The calculations and results of the regression analysis are presented in

Chapter 4.

3.7 Model for study in Phase 2

The Kipps Elementary School was chosen to evaluate the cost effectiveness of the system

for full, half and quarter roof area. Data on energy consumption and utility bills for the

year of 2005 was used to develop load profiles for different months to evaluate the cost-

benefit of the system as discussed in detail in 4.6.2. The roof of the school is assumed to

32

be flat. The data was collected from June 2005 to January 2006. Only day time values

were used for the regression model.

3.8 Summary of Methodology

The study starts with identifying the parameters affecting performance explained in

Chapter 2. The experimental setup is constructed and the data acquisition system is

chosen based of the requirements of data collected. The data collected is analyzed and

studied through charts and the regression models as explained in chapter 4.

33

Chapter 4: Results

4.1 Relationship between power and the independent variables

The data collected from the experimental setup was plotted to check if the relationship

between the dependent variable and the independent variables were linear. This is one of

the assumptions for multiple linear regression analysis. Wherever major deviations from

linearity were observed, the independent variable was transformed to satisfy the condition

of linearity. X-Y plots are shown in Fig 4.1 to 4.3.

Power/area v/s Solar Radiation

0.00

5.00

10.00

15.00

20.00

25.00

30.00

35.00

0 50 100 150 200 250 300 350

Solar Radiation (watt/m2)

Po

wer

/are

a (

wat

t/m

2)

Power/sq.m

Fig 4.1 – Power per unit area, for different solar radiations

Power/area v/s Altitude

0.00

5.00

10.00

15.00

20.00

25.00

30.00

0 10 20 30 40 50 60 70 80

Altitude (degree)

Po

wer

/are

a (w

att/

m2)

Power/sq.m

Fig 4.2 – Power per unit area, for different altitudes

34

Power/area v/s temperature

0.00

5.00

10.00

15.00

20.00

25.00

30.00

35.00

0 10 20 30 40 50 60 70 80 90 100

Temperature (deg F)

Po

wer

/are

a (w

att/

m2)

Power/sq.m

Fig 4.3 – Power per unit area, for different temperatures

4.2 Multiple Linear Regression Analysis

Multiple linear regression analysis was used to establish an estimate for the relationship

between the independent variables (solar radiation, temperature, altitude, and azimuth)

and the dependent variable, power produced per unit area. The model developed was

used to predict the electrical power production for each month for different roof coverage

areas in the Kipps Elementary School located in Blacksburg, Virginia.

Assumption and Limitation

The relationship between the variables is assumed to be linear from the plots. In practice

this assumption is difficult to be confirmed, but fortunately multiple regression

procedures are not greatly affected by minor deviations from this assumption. If the

bivariate plots indicate curvature in relationship, we may consider transforming the

variables.

The major conceptual limitation of regression techniques is that we can only ascertain

relationships, but never be sure about the underlying casual mechanism, this must come

theory and the knowledge of the system under study.

35

4.3 Regression Model using Statview

Statview is used for the Multiple Linear Regression Analysis. Statview statistics software

helps to visualize and uncover data patterns that may impact the research, development,

and production activities. The detailed output for the models is available in the Appendix

A.

Regression Model

The hypothesized model from Chapter 1 is shown in Equation 4.1.

P = bo + b1* Rad + b2*Azimuth + b 3 *Altitude – b 4*Temp – Equation 4.1

where P is power produced per unit area (watt/sq.m)

Rad is the solar radiation incident at that time (watt/sq.m)

Temp is the temperature of the panel (deg F)

Azimuth and Altitude are calculated based on the time of the day (deg)

36

Output from the Multiple Linear Regression Analysis using Statview is given below:

4004

0

.971

.942

.942

1.838

Count

Num. Missing

R

R Squared

Adjusted R Squared

RMS Residual

Regression SummaryPower/sq.m vs. 4 Independents

4 221542.761 55385.690 16385.968 <.0001

3999 13516.893 3.380

4003 235059.654

DF Sum of Squares Mean Square F-Value P-Value

Regression

Residual

Total

ANOVA TablePower/sq.m vs. 4 Independents

-17.619 .708 -17.619 -24.892 <.0001

.147 .001 .950 237.744 <.0001

.011 .001 .106 21.342 <.0001

.031 .002 .075 16.413 <.0001

.032 .010 .014 3.304 .0010

Coeff icient Std. Error Std. Coeff. t-Value P-Value

Intercept

Rad

Azimuth

Altitude

Temp

Regression CoefficientsPower/sq.m vs. 4 Independents

Fig 4.4 – Sample output of Regression Analysis from Statview

37

4004

0

.967

.936

.936

1.940

Count

Num. Missing

R

R Squared

Adjusted R Squared

RMS Residual

Regression SummaryPower/sq.m vs. 3 Independents

3 220003.164 73334.388 19482.466 <.0001

4000 15056.490 3.764

4003 235059.654


Regression

Residual

Total

ANOVA TablePower/sq.m vs. 3 Independents

-21.521 .722 -21.521 -29.824 <.0001

.147 .001 .950 225.331 <.0001

.011 .002 .027 6.344 <.0001

.119 .009 .054 12.995 <.0001

Coeff icient Std. Error Std. Coeff. t-Value P-Value

Intercept

Rad

Altitude

Temp

Regression CoefficientsPower/sq.m vs. 3 Independents

1.000 -.526 -.175 .223

-.526 1.000 .457 -.034

-.175 .457 1.000 .180

.223 -.034 .180 1.000

Altitude Azimuth Temp Rad

Altitude

Azimuth

Temp

Rad4004 observations w ere used in this computation.

Correlation Matrix

Fig 4.5 – Final output of Regression Analysis from Statview

The regression models were developed with and without considering Azimuth. Azimuth

was observed to have a strong correlation with Altitude. Also eliminating Azimuth from

the model did not affect the model significantly.

Other regression models were developed using different combinations of Rad, Temp,

Rad2, Temp2, Altitude, Azimuth, Modified Azimuth (180-Azimuth). The best model

developed considering the R-square values and t-values is:

38

Power/m2 = -21.521 + 0.01*Altitude + 0.119*Temp + 0.147*Rad – Equation 4.2

(-29.824) (6.3444) (12.995) (225.331)

This model could then be used to estimate power production per unit area for any

combination of levels for the independent variable set. Using the TMY weather data and

given month, day and time, the model can be applied to estimate power production for a

given roof area.

4.4 Cost analysis case study

Kipps Elementary School located on Prices Fork Road in Blacksburg, Virginia was

chosen as the building to study the cost-benefit of the thin film photovoltaic roofing

system compared to a non-electricity producing conventional roof. The school houses

approximately 500 students from grades K-5. The roof of the school building was

assumed to be flat. The usable roof area is about 20,000sq.ft.

Fig 4.6 – Kipps Elementary School

4.5 Simple Payback Analysis

A simplified form of cost/benefit analysis is the simple payback technique. In this

method, the total first cost of the improvement is divided by the first-year energy cost

savings produced by the improvement. This method yields the number of years required

39

for the improvement to pay for itself. For new construction, it can be used to evaluate

conventional construction to energy-efficient design alternatives.

In simple payback analysis, you are assuming that the service life of the energy efficiency

measure will equal or exceed the simple payback time. Simple payback analysis provides

a relatively easy way to examine the overall costs and savings potentials for a variety of

project alternatives. While the payback period analysis does not take into consideration

the time dependent value of money, nor the total accumulated cost or savings over the life

of the system, for systems with equal expected lives, simple payback period can be

applied to determine relative performance among alternatives.

Simple Payback time (years) = Total cost of the system/ Annual Savings

– Equation 4.3

4.6 Simple Payback Time Calculator A spreadsheet was developed in Excel to calculate the simple payback time for the BIPV

roofing system based on the energy consumption data entered, the area of roof coverage,

utility rates and demand charge. This spreadsheet was developed considering the TMY

files for a typical day of the month and using the load profile for a typical school day.

The limitation of this model and scope for future improvement is discussed in Chapter 5

in detail.

4.6.1 Energy Consumption data

The energy consumption data from year 2005 for Kipps Elementary School provided by

Montgomery County Public Schools was used for this study and is shown in Table 4.1

40

Table 4.1 – Energy consumption data for Kipps Elementary School, year 2005

Energy consumption data

Month Electricity/day (kWh/day) No. of days

Electricity (kWh)

Jan 2003 31 62100 Feb 2357 28 66000 Mar 2187 31 67800 Apr 2640 30 79200 May 2274 31 70500 Jun 2510 30 75300 Jul 2303 31 71400 Aug 2303 31 71400 Sep 3100 30 93000 Oct 2487 31 77100 Nov 2510 30 75300 Dec 2032 31 63000

4.6.2 Load profile for typical school day

The load profile for a typical school day from Marion County, Florida is shown below

and is proportionately altered to estimate the load profiles for the different months based

on the Kipps Elementary school data for year 2005.

Fig 4.7 – Load profile for a typical school day

Hourly Electrical Load Profile - Typical school day

0

50100150200

250300350

0:00

2:00

4:00

6:00

8:00

10:00

12:00

14:00

16:00

18:00

20:00

22:00

24:00

:00

Hour

Po

wer

(kW

)

Series1

A

B

C

D

41

In the chart above,

Area A depicts the base load during the non-operational hours.

Area B depicts the HVAC and other equipment starting at the same time creating an

unnecessary peak load and raising the demand charge.

Area C depicts the peak load.

Area D depicts the equipment left running after the class.

The load profile for different months of the year for Kipps Elementary School located in

Blacksburg was obtained by scaling the above profile using the utility records obtained

from Montgomery County Public School. The load profiles are shown in Fig 4.8 through

4.19.

Typical day in January

0.00

50.00

100.00

150.00

200.00

0:00

2:00

4:00

6:00

8:00

10:00

12:00

14:00

16:00

18:00

20:00

22:00

24:00

:00

Electrical Load (kW)

Fig 4.8 – Electricity Load Profile for typical day in January

Typical day in February

0.0050.00

100.00150.00200.00

0:00

2:004:00 6:00

8:0010:00

12:0014:00

16:00

18:0020:00

22:00

24:00:00


Fig 4.9 – Electricity Load Profile for typical day in February

42

Typical Day in March

0.0050.00

100.00150.00200.00

0:00

2:00

4:00 6:00

8:00

10:0012

:0014

:0016

:0018

:0020:00

22:00

24:00

:00


Fig 4.10 – Electricity Load Profile for typical day in March

Typical day in April

0.0050.00

100.00150.00200.00250.00

0:00

2:00

4:00

6:00

8:00

10:00

12:00

14:00

16:00

18:00

20:00

22:00

24:00

:00


Fig 4.11 – Electricity Load Profile for typical day in April

Typical day in May

0.0050.00

100.00150.00

200.00

0:00

2:00

4:00

6:00

8:00

10:0012

:0014

:0016

:0018

:0020

:0022

:00

24:00:00


Fig 4.12 – Electricity Load Profile for typical day in May

43

Typical day in June

0.0050.00

100.00150.00200.00250.00

0:00

2:00

4:00

6:00

8:00

10:00

12:00

14:00

16:00

18:00

20:00

22:00

24:00

:00


Fig 4.13 – Electricity Load Profile for typical day in June

Typical day in July

0.0050.00

100.00150.00200.00

0:00

2:00

4:00

6:00

8:00

10:00

12:00

14:00

16:00

18:00

20:00

22:00

24:00

:00


Fig 4.14 – Electricity Load Profile for typical day in July

Typical day in August

0.0050.00

100.00150.00200.00

0:00

2:00

4:00

6:00

8:00

10:0012:00

14:00

16:00

18:00

20:00

22:00

24:00

:00


Fig 4.15 – Electricity Load Profile for typical day in August

44

Typical day in September

0.0050.00

100.00150.00200.00250.00300.00

0:00

2:00

4:00

6:00

8:0010

:0012

:0014

:0016:00

18:0020:00

22:00

24:00:00


Fig 4.16 – Electricity Load Profile for typical day in September

Typical day in October

0.0050.00

100.00150.00200.00250.00

0:00

2:004:00

6:008:00

10:00

12:00

14:00

16:0018:00

20:0022:00

24:00:00


Fig 4.17 – Electricity Load Profile for typical day in October

Typical day in November

0.0050.00

100.00150.00200.00250.00

0:00

2:00

4:00

6:00

8:00

10:00

12:00

14:00

16:00

18:00

20:00

22:00

24:00

:00


Fig 4.18 – Electricity Load Profile for typical day in November

45

Typical day in December

0.00

50.00

100.00

150.00

200.00

0:00

2:00

4:00

6:00

8:00

10:00

12:00

14:00

16:00

18:00

20:00

22:00

24:00

:00


Fig 4.19 – Electricity Load Profile for typical day in December

4.6.3 Electricity production prediction using the Regression Model

The electricity production per unit area for each month was calculated using the

Regression Model (Equation 4.2) and is shown below.

Power/m2 = -21.521 + 0.01*Altitude + 0.119*Temp + 0.147*Rad – Equation 4.2

where,

Power/m2 = Power produced per sq.m area of panel (watt/m2)

Altitude = Solar altitude based on time of the day (degree)

Temp = Temperature of the panel (degree F)

Rad = Solar radiation incident upon the panels at any particular time (watt/m2)

Using the model, electricity production per unit area for each hour of the 15th day in each

month was calculated. The tables are included in Appendix B.

4.6.4 Electricity production for different roof areas

Based on the area of the roof covered with the PV panels (full, half, quarter roof), the

electricity production was calculated and compared to the electricity consumption as

shown in the following figures. For calculation of the energy production per unit area

using the regression model developed, TMY files were used for a typical day in each

month.

46

JANUARY

0.00

20.00

40.00

60.00

80.00

100.00

120.00

140.00

160.00

180.00

0:00

1:00

2:00

3:00

4:00

5:00

6:00

7:00

8:00

9:00

10:00

11:0012

:0013

:0014

:0015

:0016:00

17:0018

:0019

:0020

:0021

:0022:00

23:00

24:00

:00

TIME

ELE

CT

RIC

ITY

(KW

H)

ELECTRICITY CONSUMED kWh ELECTRICTY PRODUCED (FULL ROOF) kWh

ELECTRICITY PRODUCED (HALF ROOF) kWh ELECTRICITY PRODUCED (QUARTER ROOF) kWh

Fig 4.20 – Electricity chart for January

February

0.00

20.00

40.00

60.00

80.00

100.00

120.00

140.00

160.00

180.00

200.00

0:001:0

02:0

03:0

04:00

5:006:00 7:0

08:0

09:0

010:0

011:0

012:0

013

:0014

:0015:0

016:0

017:0

018

:0019

:0020

:0021:0

022:0

023:0

0

24:00:00

Time

Ele

ctri

city



Fig 4.21 – Electricity chart for February

47

March

0.00

20.00

40.00

60.00

80.00

100.00

120.00

140.00

160.00

180.00

200.00

0:001:0

02:00

3:00

4:00 5:006:0

07:00 8:00 9:00

10:00

11:0012:0

013:0

014

:0015:00

16:00

17:00

18:00

19:00

20:0021:0

022

:0023

:00

24:00 :00

Time

Ele

ctri

city



Fig 4.22 – Electricity chart for March

April

0.00

50.00

100.00

150.00

200.00

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0:00

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18:00

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23:00

24:00:00

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Ele

ctri

city



Fig 4.23 – Electricity chart for April

48

May

0.00

20.00

40.00

60.00

80.00

100.00

120.00

140.00

160.00

180.00

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0:00 1:00 2:003:00

4:00

5:00 6:00 7:00 8:00 9:00

10:0011:0

012

:0013

:0014

:0015

:0016:00

17:0018:0

019:0

020

:0021:00

22:0023:0

0

24:00 :00

Time

Ele

ctri

city



Fig 4.24 – Electricity chart for May

June

0.00

50.00

100.00

150.00

200.00

250.00

0:00

1:002:0

03:0

04:0

05:0

06:0

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011

:0012:0

013:0

014

:0015

:0016:0

017

:0018

:0019:0

020

:0021

:0022:0

023

:00

24:00:00

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Ele

ctri

city



Fig 4.25 – Electricity data for June

49

July

0.00

20.00

40.00

60.00

80.00

100.00

120.00

140.00

160.00

180.00

200.00

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18:00

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24:00

:00

Time

Ele

ctri

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Fig 4.26 – Electricity data for July

August

0.00

20.00

40.00

60.00

80.00

100.00

120.00

140.00

160.00

180.00

200.00

0:00

1:00

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4:005:0

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17:00

18:00

19:00

20:00

21:00

22:00

23:00

24:00:00

Time

Ele

ctr

icit

y



Figure 4.27 – Electricity data for August

50

September

0.00

50.00

100.00

150.00

200.00

250.00

300.00

0:00

1:00

2:00

3:00

4:005:0

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20:00

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23:00

24:00:00

Time

Ele

ctr

icit

y



Figure 4.28– Electricity data for September

October

0.00

50.00

100.00

150.00

200.00

250.00

0:00

1:00 2:00

3:00

4:00

5:00

6:00

7:00

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17:00

18:00

19:00

20:00

21:00

22:00

23:00

24:00:00

Time

Ele

ctri

city



Figure 4.29 – Electricity data for October

51

November

0.00

50.00

100.00

150.00

200.00

250.00

0:00

1:00

2:00

3:00

4:00

5:00

6:00

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17:00

18:00

19:00

20:00

21:00

22:00

23:00

24:00 :00

Time

Ele

ctri

city



Figure 4.30– Electricity data for November

December

0.00

20.00

40.00

60.00

80.00

100.00

120.00

140.00

160.00

180.00

0:00 1:00

2:003:0

04:00

5:00 6:00

7:00

8:00 9:00

10:00

11:00

12:00

13:00

14:00

15:00

16:00

17:00

18:00

19:00

20:00

21:00

22:00

23:00

24:00:0

0

Time

Ele

ctr

icit

y



Figure 4.31 – Electricity data for December

Note: It has been observed that the peak load occurs when all the equipment is switched

on in the morning. At this time, the power production is low or almost zero. By changing

52

the pattern of equipment operation, huge savings can be made in electricity bills by

cutting down the peak load and demand charges.

The detailed tables showing calculation of electricity drawn from the utility at each hour

of the day in each month, the peak load, the electricity bills, demand charges and savings

is presented in Appendix B.

4.6.5 Simple Payback time

The total electricity bills and savings are given below. Detailed calculations are in

Appendix B.

Data :

Area of full roof: 1810.33 sq.m (approx.)

Area of panel: 2.16 sq.m

Cost of panel: $748

Demand charge: $8/kW

Utility rate: $0.08/kWh

Table 4.2 – Electricity bills for different roof coverage

WITHOUT PV FULL ROOF HALF ROOF QUARTER ROOF

MONTH Total Electricity

Bill Total Electricity



Bill January $6,246.01 $4,766.17 $5,475.66 $5,830.40 February $6,783.80 $5,151.27 $5,883.99 $6,267.76 March $6,819.31 $4,702.35 $5,672.24 $6,177.91 April $8,020.25 $5,784.07 $6,795.23 $7,334.76 May $7,090.88 $4,124.83 $5,515.74 $6,282.24 June $7,625.32 $4,817.16 $6,119.57 $6,842.46 July $7,181.40 $4,757.10 $5,875.95 $6,509.84 August $7,181.40 $4,759.75 $5,877.28 $6,458.48 September $9,417.72 $7,315.82 $8,241.20 $8,786.24 October $7,754.70 $5,450.96 $6,502.09 $7,038.53 November $7,625.32 $6,036.77 $6,742.08 $7,124.38 December $6,336.53 $4,938.28 $5,565.38 $5,905.27

53

Table 4.3 – Savings for different roof coverage

FULL ROOF HALF ROOF QUARTER ROOF MONTH savings savings Savings January $1,479.84 $770.35 $415.61 February $1,632.53 $899.81 $516.04 March $2,116.96 $1,147.07 $641.40 April $2,236.18 $1,225.02 $685.49 May $2,966.05 $1,575.14 $808.64 June $2,808.16 $1,505.75 $782.86 July $2,424.30 $1,305.45 $671.56 August $2,421.65 $1,304.12 $722.92 September $2,101.90 $1,176.52 $631.48 October $2,303.74 $1,252.61 $716.17 November $1,588.55 $883.24 $500.94 December $1,398.25 $771.15 $431.26 ANNUAL $25,478.11 $13,816.23 $7,524.37

Cost of the system:

Full roof area: $ 627,572.00

Half roof area: $ 314,160.00

Quarter roof area: $ 157,080.00

Simple payback time = Total cost of system / Annual savings –Equation 4.3

For different roofs areas:

Full Roof Area : Simple Payback time = 24.63 years

Half Roof Area : Simple Payback time = 22.74 years

Quarter Roof Area : Simple Payback time = 20.88 years

4.6.6 Simple Payback time for different utility rates and rebates

The simple payback period was calculated for different utility rates and rebate amounts to

observe at what point the system appears cost-effective compared to the conventional

non-electricity producing roofing system. The results are summarized in tables 4.4

through 4.6.

54

Table 4.4 – Simple Payback period for full roof coverage

FULL ROOF AREA simple payback time for different utility rates and rebates Rebate Utility rate 0% 10% 20% 30% 40% 50% 60% 70% 80% $ 0.06 31.61 28.45 25.29 22.13 18.97 15.80 12.64 9.48 6.32

$ 0.08 24.63 22.17 19.71 17.24 14.78 12.32 9.85 7.39 4.93

$ 0.10 20.18 18.16 16.14 14.12 12.11 10.09 8.07 6.05 4.04

$ 0.12 17.09 15.38 13.67 11.96 10.25 8.54 6.84 5.13 3.42

$ 0.14 14.82 13.34 11.85 10.37 8.89 7.41 5.93 4.45 2.96

$ 0.16 13.08 11.77 10.46 9.16 7.85 6.54 5.23 3.92 2.62

$ 0.18 11.71 10.54 9.37 8.20 7.03 5.85 4.68 3.51 2.34

$ 0.20 10.60 9.54 8.48 7.42 6.36 5.30 4.24 3.18 2.12

Table 4.5 – Simple Payback period for half roof coverage

HALF ROOF AREA simple payback time for different utility rates and rebates Rebate Utility rate 0% 10% 20% 30% 40% 50% 60% 70% 80% $ 0.06 28.55 25.69 22.84 19.98 17.13 14.27 11.42 8.56 5.71

$ 0.08 22.74 20.46 18.19 15.92 13.64 11.37 9.10 6.82 4.55

$ 0.10 18.89 17.00 15.11 13.23 11.34 9.45 7.56 5.67 3.78

$ 0.12 16.16 14.54 12.93 11.31 9.70 8.08 6.46 4.85 3.23

$ 0.14 14.12 12.71 11.29 9.88 8.47 7.06 5.65 4.24 2.82

$ 0.16 12.53 11.28 10.03 8.77 7.52 6.27 5.01 3.76 2.51

$ 0.18 11.27 10.14 9.02 7.89 6.76 5.63 4.51 3.38 2.25

$ 0.20 10.24 9.12 8.19 7.17 6.14 5.12 4.09 3.07 2.05

55

Table 4.6 – Simple Payback period for quarter roof coverage

QUARTER ROOF AREA simple payback time for different utility rates and rebates Rebate Utility rate 0% 10% 20% 30% 40% 50% 60% 70% 80% $ 0.06 25.67 23.11 20.54 17.97 15.40 12.84 10.27 7.70 5.13

$ 0.08 20.88 18.79 16.70 14.61 12.53 10.44 8.35 6.26 4.18

$ 0.10 17.59 15.83 14.07 12.31 10.55 8.79 7.04 5.28 3.52

$ 0.12 15.20 13.68 12.16 10.64 9.12 7.60 6.08 4.56 3.04

$ 0.14 13.38 12.04 10.70 9.36 8.03 6.69 5.35 4.01 2.68

$ 0.16 11.95 10.75 9.56 8.36 7.17 5.97 4.78 3.58 2.39

$ 0.18 10.79 9.71 8.63 7.55 6.48 5.40 4.32 3.24 2.16

$ 0.20 9.84 8.86 7.87 6.89 5.90 4.92 3.94 2.95 1.97

4.6.7 Simple Payback period for different utility rates and demand charge

Table 4.7 – Simple payback period for Utility rate = $0.08/kWh

SIMPLE PAYBACK PERIOD FOR DIFFERENT DEMAND CHARGES

Utility rate = $ 0.08 WITH NO REBATES DEMAND CHARGE $8/kW $16/ kW $24/ kW FULL ROOF 24.63 22.05 19.96 HALF ROOF 22.74 19.17 16.58 QUARTER ROOF 20.88 16.67 13.87




56






Utility rate = $ 0.14 WITH NO REBATES DEMAND CHARGE $8/kW $16/kw $24/kw FULL ROOF 14.82 13.84 12.99 HALF ROOF 14.12 12.66 11.47 QUARTER ROOF 13.38 11.51 10.11







57




4.7 Summary of Results

The calculation of simple payback periods for different utility rates and demand charges

for different roof coverage shows that at present the system is not economically feasible

because of the high cost. The load profile reveals that a peak load occurs at around 5:00 –

6:00A.M in the morning when all the equipment is switched on simultaneously. At this

hour of the day, the electricity production by the PV panel is very low and almost zero so

the effect of the PV system on reducing the demand charge is not observed. The system

can prove economical feasible if this load is distributed more evenly during the course of

the day. Limitations of the model and scope for future improved models are discussed in

Chapter 5. The rebates necessary to make the system cost-effective is also discussed in

chapter 5.

58

Chapter 5: Conclusions and Discussion

5.1 Conclusions

The model was developed to predict the electricity power production for the system for

any building when the levels of the variables (solar radiation, solar altitude, azimuth and

temperature) are known.

The model was applied to the Kipps Elementary School located in Blacksburg, Virginia.

From the results, it can be concluded that at current utility rate of about 8 cents/kWh and

a demand charge of $8/kW, the system is not economically feasible. However with a

rebate of about 80%, the simple payback period drops to about 4.93 years for full roof,

4.55 years for half roof and 4.18 years for quarter roof area. Not much difference is

noticed in the three different roof coverage because the peak load occurs early in the

morning when the PV panel production is low. By distributing this load evenly

throughout the day, big savings can be made in the demand charge. At higher utility rates

like 18 cents/kWh and 20 cents/kWh, the system appears cost-effective with about 50%

rebates from the Government or utilities. With rebates, the demand for the PV panels

will rise gradually leading to more production of panels and a likely drop in price thereby

making the system more cost-effective. The study has a few limitations which can be

improved in future as mentioned in 5.2.

5.2 Limitation of the study and recommendations

The model developed using multiple linear regression analysis, shows a positive

relationship between temperature and the power produced by the panel. From the

literature study, it was noted that at very high temperatures, the power production by the

panel drops. This was not observed in the data collected since extremes temperatures

were not experienced during the time of collection. The study can be improved by

developing separate models for very warm, cold, clear and cloudy days to make the

prediction more accurate.

59

The electricity load profiles for a typical school day were used in the study after scaling it

to the electricity consumption data for each month for Kipps Elementary School obtained

for year 2005 from the Montgomery County Public School. The load profiles vary for

warm, cold and moderate days. Accurate predictions can be made using the actual load

profile for the building. However due to unavailability of data, typical day load profile

was used.

For calculation of the energy production per unit area using the regression model

developed, TMY files were used for a typical day in each month. The prediction can be

made more accurate using different data for warm, cold and moderate days.

As mentioned in earlier chapter, the peak load that occurs in the morning was responsible

for not making the system appear economically feasible. By distributing this load, the

system can appear cost-effective at lower rebates and utility rates.

The BIPV roofing system can be made economically feasible with rebates from the

Government initially and also by distributing the loads throughout the day.

60

References

1. Deo Prasad and Mark Snow

Designing with Solar Power : a source book for Building integrated photovoltaic

(2005, Mulgrave, Vic.: Images; London; Sterling, VA: Earthscan)

2. Patrina Eiffert and Gregory Kiss

Building integrated photovoltaic designs for commercial and institutional structures: a

source book for Architects

(2000, Golden, CO : National Renewable Energy Laboratory)

3. Othman Humm and Peter Toggweiler

Photovoltaics in Architecture: the integration of photovoltaic cells in building

envelopes

(1993, Basel ; Boston : Birkhäuser)

4. M.Oliver and T. Jackson

Energy and economic evaluation of building integrated photovoltaics

(Energy, Volume 26, Issue.4, April 2001, pp 431-459)

5. H. Yang, G. Zheng, C. Lou, D. An and J. Burnett

Grid-connected building integrated photovoltaics: a Hong Kong case study

(Solar Energy, Volume 76, Issues 1-3, January-March 2004, Pages 55-59)

6. National Instruments

Measurement and Automation Catalogue

DAQ, SCX1-1102/B/C User Manual

Getting Started with SCXI

7. ASHRAE Handbook: Fundamentals (SI edition)

(1985, Atlanta, Ga.: American Society of Heating, Refrigerating, and Air-

Conditioning Engineers)

61

8. United Solar Systems Corp.

(www.unisolar.com)

9. G.Z. Brown and Mark DeKay

Sun, wind, and light: architectural design strategies

(2001, New York: Wiley)

10. Powerlight: Solar electric systems

(www.powerlight.com)

11. Solar integrated: Solar roofing solutions

(www.solarintegrated.com)

62

Appendix A – Regression Analysis

Dependent variable : Power/m2

Independent variables : Solar Radiation (Rad);

Solar Altitude (Altitude);

Temperature (Temp)

Solar radiation greater than 1watt/m2 and less than 50 watt/m2 were used for the analysis;

at very high solar radiations the peak power was observed.

Statview summary

4004

0

.967

.936

.936

1.940

Count

Num. Missing

R

R Squared

Adjusted R Squared

RMS Residual

Regression SummaryPow er/sq.m vs. 3 Independents

3 220003.164 73334.388 19482.466 <.0001

4000 15056.490 3.764

4003 235059.654


Regression

Residual

Total

ANOVA TablePow er/sq.m vs. 3 Independents

-21.521 .722 -21.521 -29.824 <.0001

.011 .002 .027 6.344 <.0001

.119 .009 .054 12.995 <.0001

.147 .001 .950 225.331 <.0001

Coefficient Std. Error Std. Coeff . t-Value P-Value

Intercept

Altitude

Temp

Rad

Regression CoefficientsPow er/sq.m vs. 3 Independents

1.000 -.526 -.175 .223

-.526 1.000 .457 -.034

-.175 .457 1.000 .180

.223 -.034 .180 1.000

Altitude Azimuth Temp Rad

Altitude

Azimuth

Temp

Rad

4004 observations w ere used in this computation.

Correlation Matrix

63

Appendix B – Electricity production

Note: The calculations are based on TMY files for a typical day in each month. The panel

used is PVL series from UniSolar.

B-1 Electricity production in each month using the Regression Model

REGRESSION MODEL: Power/m2 = -21.521 + 0.01*Altitude + 0.119*Temp + 0.147*Rad where Power/m2 = Power produced per sq.m area of panel (watt/m2) Altitude = Solar altitude based on time of the day (degree) Temp = Temperature of the panel (degree F) Rad = Solar radiation incident upon the panels at any particular time (watt/m2)

Table B-1-1

JANUARY

Time Altitude Temp (degree F)

Rad (Wh/m2)

Energy (Wh/m2)

Energy (kWh/m2)

8:00 3.6 33.3 146 3.93 0.0039 9:00 12.9 34.5 267 21.96 0.0220

10:00 20.8 36.1 354 35.03 0.0350 11:00 26.6 37.8 399 41.89 0.0419 12:00 29.5 39.2 433 47.09 0.0471 13:00 29.3 39.6 422 45.51 0.0455 14:00 25.9 39.7 445 48.88 0.0489 15:00 19.7 40.1 374 38.43 0.0384 16:00 11.6 38.3 255 20.64 0.0206

Energy/m2/day 0.3034 kWh/m2/day Energy/m2/month 9.4043 kWh/m2

64

Table B-1-2

FEBRUARY


Rad (Wh/m2)

Energy (Wh/m2)

Energy (kWh/m2)

8:00 5.8 33.08 294 25.69 0.0257 9:00 15.9 35.60 412 43.44 0.0434

10:00 24.7 37.40 436 47.27 0.0473 11:00 31.4 39.38 433 47.13 0.0471 12:00 35.2 41.36 405 43.29 0.0433 13:00 35.6 42.26 391 41.34 0.0413 14:00 32.3 43.16 398 42.44 0.0424 15:00 26.1 44.06 365 37.64 0.0376 16:00 17.6 42.08 307 28.79 0.0288 17:00 7.7 40.10 143 4.35 0.0043


Table B-1-3

MARCH


Rad (Wh/m2)

Energy (Wh/m2)

Energy (kWh/m2)

7:00 1.0 42.62 176 9.43 0.0094 8:00 12.3 45.32 278 24.86 0.0249 9:00 23.1 48.56 366 38.29 0.0383

10:00 32.7 51.26 372 39.59 0.0396 11:00 40.3 53.60 428 48.18 0.0482 12:00 44.7 55.22 451 51.79 0.0518 13:00 45.0 57.20 488 57.47 0.0575 14:00 41.1 58.28 472 55.21 0.0552 15:00 33.9 58.46 444 51.04 0.0510 16:00 24.5 57.74 364 39.10 0.0391 17:00 13.8 55.22 217 17.09 0.0171


65

Table B-1-4

APRIL


Rad (Wh/m2)

Energy (Wh/m2)

Energy (kWh/m2)

7:00 9.8 53.42 249 21.54 0.0215 8:00 21.6 56.30 333 34.35 0.0343 9:00 33.1 59.00 399 44.48 0.0445

10:00 43.6 60.98 419 47.76 0.0478 11:00 52.1 62.96 434 50.29 0.0503 12:00 57.0 64.94 428 49.69 0.0497 13:00 56.6 65.30 450 52.97 0.0530 14:00 51.0 65.84 449 52.83 0.0528 15:00 42.1 66.20 412 47.34 0.0473 16:00 31.4 64.58 362 39.69 0.0397 17:00 19.9 62.78 261 24.52 0.0245


Table B-1-5

MAY


Rad (Wh/m2)

Energy (Wh/m2)

Energy (kWh/m2)

6:00 5.6 58.64 247 21.82 0.0218 7:00 17.3 62.42 383 42.38 0.0424 8:00 29.2 65.84 443 51.73 0.0517 9:00 41.0 68.00 443 52.10 0.0521

10:00 52.3 70.16 459 54.82 0.0548 11:00 61.9 71.78 450 53.79 0.0538 12:00 67.6 73.04 454 54.58 0.0546 13:00 66.2 74.12 443 53.08 0.0531 14:00 58.6 74.48 423 50.11 0.0501 15:00 48.2 74.48 372 42.51 0.0425 16:00 36.6 73.58 384 44.05 0.0440 17:00 24.8 71.78 267 26.52 0.0265 18:00 12.9 69.44 101 1.72 0.0017


66

Table B-1-6

JUNE


Rad (Wh/m2)

Energy (Wh/m2)

Energy (kWh/m2)

6:00 9.6 65.30 197 15.30 0.0153 7:00 21.0 68.54 292 29.77 0.0298 8:00 32.8 71.06 335 36.51 0.0365 9:00 44.7 72.86 420 49.34 0.0493

10:00 56.4 75.02 437 52.21 0.0522 11:00 67.2 76.64 446 53.83 0.0538 12:00 74.3 78.08 439 53.05 0.0530 13:00 72.6 78.98 429 51.67 0.0517 14:00 63.6 78.98 463 56.57 0.0566 15:00 52.4 79.34 434 52.24 0.0522 16:00 40.5 78.62 404 47.63 0.0476 17:00 28.6 77.54 319 34.89 0.0349 18:00 17.0 75.02 190 15.51 0.0155


Table B-1-7

JULY


Rad (Wh/m2)

Energy (Wh/m2)

Energy (kWh/m2)

6:00 9.1 69.62 175 12.58 0.0126 7:00 20.4 72.68 276 27.90 0.0279 8:00 32.1 75.74 353 39.70 0.0397 9:00 44.0 78.62 407 48.10 0.0481

10:00 55.8 80.24 406 48.27 0.0483 11:00 66.8 81.86 401 47.84 0.0478 12:00 74.8 83.48 370 43.55 0.0436 13:00 74.0 83.30 393 46.90 0.0469 14:00 65.3 82.94 367 42.95 0.0430 15:00 54.0 82.76 376 44.14 0.0441 16:00 42.2 81.32 287 30.77 0.0308 17:00 30.3 80.06 218 20.36 0.0204 18:00 18.6 78.62 114 4.78 0.0048


67

Table B-1-8

AUGUST


Rad (Wh/m2)

Energy (Wh/m2)

Energy (kWh/m2)

6:00 5.6 66.02 116 3.44 0.0034 7:00 17.0 69.26 281 28.20 0.0282 8:00 28.9 72.50 405 46.93 0.0469 9:00 40.8 75.74 445 53.32 0.0533

10:00 52.3 77.36 452 54.65 0.0547 11:00 62.7 78.98 471 57.74 0.0577 12:00 69.7 80.60 414 49.63 0.0496 13:00 69.4 80.96 408 48.78 0.0488 14:00 62.0 81.14 430 51.96 0.0520 15:00 51.5 81.50 368 42.79 0.0428 16:00 39.9 79.16 278 29.16 0.0292 17:00 28.0 77.00 219 20.12 0.0201


Table B-1-9

SEPTEMBER


Rad (Wh/m2)

Energy Wh/m2) Energy (kWh/m2)

7:00 12.6 63.86 236 20.90 0.0209 8:00 24.5 67.10 345 37.42 0.0374 9:00 36.0 70.34 420 48.95 0.0489

10:00 46.7 73.04 446 53.20 0.0532 11:00 55.5 75.02 438 52.35 0.0523 12:00 60.4 75.92 399 46.77 0.0468 13:00 59.6 77.18 397 46.62 0.0466 14:00 53.3 76.64 397 46.49 0.0465 15:00 43.8 76.46 332 36.82 0.0368 16:00 32.7 75.38 273 27.91 0.0279 17:00 21.0 73.04 144 8.55 0.0085


68

Table B-1-10

OCTOBER


Rad (Wh/m2)

Energy (Wh/m2)

Energy (kWh/m2)

7:00 7.7 53.96 236 19.67 0.0197 8:00 19.2 57.92 387 42.45 0.0425 9:00 29.9 61.16 465 54.41 0.0544

10:00 39.2 63.86 490 58.50 0.0585 11:00 46.1 65.84 508 61.45 0.0615 12:00 49.3 67.10 502 60.75 0.0608 13:00 47.8 68.00 507 61.58 0.0616 14:00 42.1 68.36 399 45.69 0.0457 15:00 33.5 67.64 378 42.43 0.0424 16:00 23.2 65.30 237 21.32 0.0213


Table B-1-11

NOVEMBER


Rad (Wh/m2)

Energy (Wh/m2)

Energy (kWh/m2)

8:00 12.70 48.02 242 19.89 0.0199 9:00 22.40 50.90 319 31.65 0.0317

10:00 30.40 52.88 427 47.84 0.0478 11:00 36.00 55.04 431 48.75 0.0487 12:00 38.20 57.02 456 52.68 0.0527 13:00 36.60 57.20 428 48.57 0.0486 14:00 31.50 57.38 376 40.89 0.0409 15:00 23.90 57.38 289 28.03 0.0280 16:00 14.40 55.22 144 6.36 0.0064


69

Table B-1-12

DECEMBER


Rad (Wh/m2)

Energy (Wh/m2)

Energy (kWh/m2)

8:00 6.7 35.96 222 15.46 0.0155 9:00 15.8 38.12 369 37.42 0.0374

10:00 23.4 40.64 384 40.00 0.0400 11:00 28.6 42.26 403 43.03 0.0430 12:00 30.8 44.24 377 39.47 0.0395 13:00 29.8 45.68 363 37.57 0.0376 14:00 25.6 46.58 365 37.93 0.0379 15:00 18.8 46.22 281 25.47 0.0255 16:00 10.1 43.34 131 2.99 0.0030


70

B-2 ELECTRICITY PRODUCTION AND UTILITY BILL CALCULATION (sample) DATA Area of full roof 19486.20 sq.ft(approx.) (assume flat roof) 1810.33 sq.m Area of roof: 1810.33 sq.m % of roof covered with PV 25.00 % Area of PV panel: 452.58 sq.m Area /panel: 2.16 sq.m No. of panels: 210 Cost per panel: $ 748.00 Total cost of panel: $ 157,080.00 Total cost of PV system: $ 157,080.00 ELECTRICITY BILL = ELECTRICITY CONSUMPTION*RATE + PEAK LOAD* TOTAL DEMAND CHARGE

Rate: $ 0.12 Basic electricity bill = Electricity from utility/day*No. of days in month* Rate

Demand charge (rate): $ 16.00 per Kw Total Demand Charge = Peak Load + Demand charge

JANUARY 31 days

TIME ELECTRICITY CONSUMED

ELECTRICITY PRODUCED


ELECTRICITY FROM UTILITY

kWh kWh/m2 kWh kWh WITHOUT PV ROOF 0:00 12.68 0.00 0.00 12.68 Peak Load: 159.75 1:00 12.68 0.00 0.00 12.68 Demand charge: $ 2,556.01 2:00 12.68 0.00 0.00 12.68 Basic electricity bill: $ 7,452.00 3:00 12.68 0.00 0.00 12.68 Total electricity bill: $ 10,008.01 4:00 12.68 0.00 0.00 12.68 5:00 25.36 0.00 0.00 25.36 WITH PV ROOF 6:00 139.47 0.00 0.00 139.47 Peak Load: 150.36 7:00 142.00 0.00 0.00 142.00 Demand charge: $ 2,405.81

71

8:00 152.14 0.00 1.78 150.36 Basic electricity bill: $ 6,941.25 9:00 152.14 0.02 9.94 142.20 Total Electricity bill: $ 9,347.06

10:00 152.14 0.04 15.85 136.29 11:00 157.22 0.04 18.96 138.26 SAVINGS: $ 660.96 12:00 159.75 0.05 21.31 138.44 13:00 159.75 0.05 20.60 139.15 14:00 157.22 0.05 22.12 135.09 15:00 133.13 0.04 17.39 115.73 16:00 88.75 0.02 9.34 79.41 17:00 83.68 0.00 0.00 83.68 18:00 76.07 0.00 0.00 76.07 19:00 57.05 0.00 0.00 57.05 20:00 38.04 0.00 0.00 38.04 21:00 22.82 0.00 0.00 22.82 22:00 17.75 0.00 0.00 17.75 23:00 12.68 0.00 0.00 12.68

24:00:00 12.68 0.00 0.00 12.68 Total electricity / day 2003.23 137.30 1865.93 FEBRUARY 28 days






72


10:00 179.02 0.05 21.39 157.63 11:00 184.99 0.05 21.33 163.66 SAVINGS: $ 848.90 12:00 187.97 0.04 19.59 168.38 13:00 187.97 0.04 18.71 169.26 14:00 184.99 0.04 19.21 165.78 15:00 156.65 0.04 17.03 139.61 16:00 104.43 0.03 13.03 91.40 17:00 98.46 0.00 1.97 96.49 18:00 89.51 0.00 0.00 89.51 19:00 67.13 0.00 0.00 67.13 20:00 44.76 0.00 0.00 44.76 21:00 26.85 0.00 0.00 26.85 22:00 20.89 0.00 0.00 20.89 23:00 14.92 0.00 0.00 14.92

24:00:00 14.92 0.00 0.00 14.92 Total electricity / day 2357.14 163.55 2193.59 MARCH 31 days






73


10:00 166.11 0.04 17.92 148.19 11:00 171.65 0.05 21.80 149.84 SAVINGS: $ 1,040.33 12:00 174.41 0.05 23.44 150.97 13:00 174.41 0.06 26.01 148.40 14:00 171.65 0.06 24.99 146.66 15:00 145.35 0.05 23.10 122.24 16:00 96.90 0.04 17.70 79.20 17:00 91.36 0.02 7.73 83.63 18:00 83.05 0.00 0.00 83.05 19:00 62.29 0.00 0.00 62.29 20:00 41.53 0.00 0.00 41.53 21:00 24.92 0.00 0.00 24.92 22:00 19.38 0.00 0.00 19.38 23:00 13.84 0.00 0.00 13.84

24:00:00 13.84 0.00 0.00 13.84 Total electricity/ day 2187.10 195.54 1991.55 APRIL 30 days






74


10:00 200.51 0.05 21.62 178.89 11:00 207.19 0.05 22.76 184.43 SAVINGS: $ 1,118.21 12:00 210.53 0.05 22.49 188.04 13:00 210.53 0.05 23.97 186.56 14:00 207.19 0.05 23.91 183.28 15:00 175.44 0.05 21.43 154.02 16:00 116.96 0.04 17.96 99.00 17:00 110.28 0.02 11.10 99.18 18:00 100.25 0.00 0.00 100.25 19:00 75.19 0.00 0.00 75.19 20:00 50.13 0.00 0.00 50.13 21:00 30.08 0.00 0.00 30.08 22:00 23.39 0.00 0.00 23.39 23:00 16.71 0.00 0.00 16.71

24:00:00 16.71 0.00 0.00 16.71 Total electricity/ day 2640.00 210.66 2429.34 MAY 31 days






75


10:00 172.72 0.05 24.81 147.91 11:00 178.48 0.05 24.34 154.14 SAVINGS: $ 1,309.05 12:00 181.36 0.05 24.70 156.66 13:00 181.36 0.05 24.02 157.34 14:00 178.48 0.05 22.68 155.80 15:00 151.13 0.04 19.24 131.89 16:00 100.76 0.04 19.94 80.82 17:00 95.00 0.03 12.00 83.00 18:00 86.36 0.00 0.78 85.58 19:00 64.77 0.00 0.00 64.77 20:00 43.18 0.00 0.00 43.18 21:00 25.91 0.00 0.00 25.91 22:00 20.15 0.00 0.00 20.15 23:00 14.39 0.00 0.00 14.39

24:00:00 14.39 0.00 0.00 14.39 Total electricity/ day 2274.19 248.56 2025.63 JUNE 30 days






76


10:00 190.63 0.05 23.63 167.00 11:00 196.99 0.05 24.36 172.62 SAVINGS: $ 1,267.82 12:00 200.16 0.05 24.01 176.16 13:00 200.16 0.05 23.38 176.78 14:00 196.99 0.06 25.60 171.38 15:00 166.80 0.05 23.64 143.16 16:00 111.20 0.05 21.56 89.65 17:00 104.85 0.03 15.79 89.06 18:00 95.32 0.02 7.02 88.30 19:00 71.49 0.00 0.00 71.49 20:00 47.66 0.00 0.00 47.66 21:00 28.59 0.00 0.00 28.59 22:00 22.24 0.00 0.00 22.24 23:00 15.89 0.00 0.00 15.89

24:00:00 15.89 0.00 0.00 15.89 Total electricity/ day 2510.00 248.25 2261.75 JULY 31 days






77


10:00 174.93 0.05 21.85 153.08 11:00 180.76 0.05 21.65 159.11 SAVINGS: $ 1,086.19 12:00 183.67 0.04 19.71 163.96 13:00 183.67 0.05 21.23 162.45 14:00 180.76 0.04 19.44 161.32 15:00 153.06 0.04 19.98 133.09 16:00 102.04 0.03 13.92 88.12 17:00 96.21 0.02 9.21 87.00 18:00 87.46 0.00 2.16 85.30 19:00 65.60 0.00 0.00 65.60 20:00 43.73 0.00 0.00 43.73 21:00 26.24 0.00 0.00 26.24 22:00 20.41 0.00 0.00 20.41 23:00 14.58 0.00 0.00 14.58

24:00:00 14.58 0.00 0.00 14.58 Total electricity/ day 2303.23 207.21 2096.02 AUGUST 31 days






78


10:00 174.93 0.05 24.73 150.19 11:00 180.76 0.06 26.13 154.63 SAVINGS: $ 1,172.70 12:00 183.67 0.05 22.46 161.22 13:00 183.67 0.05 22.08 161.60 14:00 180.76 0.05 23.52 157.24 15:00 153.06 0.04 19.37 133.70 16:00 102.04 0.03 13.20 88.84 17:00 96.21 0.02 9.10 87.11 18:00 87.46 0.00 0.00 87.46 19:00 65.60 0.00 0.00 65.60 20:00 43.73 0.00 0.00 43.73 21:00 26.24 0.00 0.00 26.24 22:00 20.41 0.00 0.00 20.41 23:00 14.58 0.00 0.00 14.58

24:00:00 14.58 0.00 0.00 14.58 Total electricity/ day 2303.23 220.28 2082.94 SEPTEMBER 30 days






79


10:00 235.44 0.05 24.08 211.37 11:00 243.29 0.05 23.69 219.60 SAVINGS: $ 1,031.61 12:00 247.22 0.05 21.17 226.05 13:00 247.22 0.05 21.10 226.12 14:00 243.29 0.05 21.04 222.25 15:00 206.01 0.04 16.66 189.35 16:00 137.34 0.03 12.63 124.71 17:00 129.49 0.01 3.87 125.62 18:00 117.72 0.00 0.00 117.72 19:00 88.29 0.00 0.00 88.29 20:00 58.86 0.00 0.00 58.86 21:00 35.32 0.00 0.00 35.32 22:00 27.47 0.00 0.00 27.47 23:00 19.62 0.00 0.00 19.62

24:00:00 19.62 0.00 0.00 19.62 Total electricity/ day 3100.00 192.79 2907.21 OCTOBER 31 days






80


10:00 188.89 0.06 26.48 162.42 11:00 195.19 0.06 27.81 167.38 SAVINGS: $ 1,169.56 12:00 198.34 0.06 27.49 170.84 13:00 198.34 0.06 27.87 170.47 14:00 195.19 0.05 20.68 174.51 15:00 165.28 0.04 19.20 146.08 16:00 110.19 0.02 9.65 100.54 17:00 103.89 0.00 0.00 103.89 18:00 94.45 0.00 0.00 94.45 19:00 70.84 0.00 0.00 70.84 20:00 47.22 0.00 0.00 47.22 21:00 28.33 0.00 0.00 28.33 22:00 22.04 0.00 0.00 22.04 23:00 15.74 0.00 0.00 15.74

24:00:00 15.74 0.00 0.00 15.74 Total electricity/ day 2487.10 211.92 2275.18 NOVEMBER 30 days






81


10:00 190.63 0.05 21.65 168.98 11:00 196.99 0.05 22.06 174.93 SAVINGS: $ 825.55 12:00 200.16 0.05 23.84 176.32 13:00 200.16 0.05 21.98 178.18 14:00 196.99 0.04 18.51 178.48 15:00 166.80 0.03 12.69 154.12 16:00 111.20 0.01 2.88 108.32 17:00 104.85 0.00 0.00 104.85 18:00 95.32 0.00 0.00 95.32 19:00 71.49 0.00 0.00 71.49 20:00 47.66 0.00 0.00 47.66 21:00 28.59 0.00 0.00 28.59 22:00 22.24 0.00 0.00 22.24 23:00 15.89 0.00 0.00 15.89

24:00:00 15.89 0.00 0.00 15.89 Total electricity/ day 2510.00 146.94 2363.06 DECEMBER 31 days






82


10:00 154.35 0.04 18.10 136.25 11:00 159.49 0.04 19.48 140.02 SAVINGS: $ 705.75 12:00 162.07 0.04 17.86 144.20 13:00 162.07 0.04 17.01 145.06 14:00 159.49 0.04 17.17 142.33 15:00 135.06 0.03 11.53 123.53 16:00 90.04 0.00 1.36 88.68 17:00 84.89 0.00 0.00 84.89 18:00 77.17 0.00 0.00 77.17 19:00 57.88 0.00 0.00 57.88 20:00 38.59 0.00 0.00 38.59 21:00 23.15 0.00 0.00 23.15 22:00 18.01 0.00 0.00 18.01 23:00 12.86 0.00 0.00 12.86

24:00:00 12.86 0.00 0.00 12.86 Total electricity/ day 2032.26 126.43 1905.83 MONTH ELECTRICITY SAVINGS PER MONTH Jan $ 660.96 Feb $ 848.90 Mar $ 1,040.33 Apr $ 1,118.21 May $ 1,309.05 Jun $ 1,267.82 Jul $ 1,086.19 Aug $ 1,172.70 Sep $ 1,031.61 Oct $ 1,169.56 Nov $ 825.55

83

Dec $ 705.75 ANNUAL SAVINGS $ 12,236.62

Annual Savings: $ 12,236.62 Cost of system: $ 157,080.00 Rebate: 60.00% Total cost (after rebate): $ 62,832.00 Simple payback time = Cost of system/Annual savings

Simple Payback time: 5.13 years

Documents

Cost-benefit analysis of a Building Integrated ... · Cost-benefit analysis of a Building Integrated Photovoltaic Roofing system for a school located in Blacksburg, Virginia Leena