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Zero peak homes: designing for zero electric peak demand in new single family residential buildings sited in California climate zone 10

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Zero peak homes: designing for zero electric peak demand in new single family residential buildings sited in California climate zone 10

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ZERO PEAK HOMES:
DESIGNING FOR ZERO ELECTRIC PEAK DEMAND IN NEW SINGLE FAMILY
RESIDENTIAL BUILDINGS SITED IN CALIFORNIA CLIMATE ZONE 10

by

Chris Buntine

________________________________________________

A Thesis Presented to the
FACULTY OF THE SCHOOL OF ARCHITECTURE
UNIVERSITY OF SOUTHERN CALIFORNIA
In Partial Fulfillment of the
Requirements for the Degree
MASTER OF BUILDING SCIENCE

December 2007

Copyright 2007 Chris Buntine
ii
Dedication
I dedicate this thesis to my two children, Sydney and Max who I hope and pray will
inherit a sustainable energy future
iii

Acknowledgements

I would like to express my sincere appreciation to the faculty at the USC School of
Architecture Master of Building Science program for their commitment to this extremely
important field and the enthusiasm and dedication which they provide the graduate
students. This thesis would not have been possible without the knowledge, skills and
guidance I have received through this program.

My thanks also to the members of my thesis committee, Professor Marc Schiler,
Professor Thomas Spiegelhalter, Professor Murray Milne and Professor Marlin Addison.
Their advice and guidance has been extremely helpful and I am extremely thankful for
the time and effort they have made to review the many drafts.

I am very grateful to my employer, Southern California Edison for providing this
opportunity to further my studies and actively apply my education to the critical
challenge of meeting the energy efficiency and demand goals for the State of California.
Thank you to the many employees of Design and Engineering Services who have made
themselves available to answer technical and policy questions.

Finally I wish to convey my extreme gratitude to my wife Sun who has on countless
occasions sacrificed her own time and priorities to allow me to complete my research.
Without her constant encouragement and support this document would not have been
possible.
iv
Table of Contents

Dedication........................................................................................................................... ii
Acknowledgements............................................................................................................iii
List of Tables ..................................................................................................................... vi
List of Figures................................................................................................................... vii
Abstract.............................................................................................................................. ix
Chapter One: Introduction .................................................................................................. 1
Chapter Two: The Peak Demand Crisis.............................................................................. 5
Electrical Consumption in California ............................................................................. 5
The Impact of Peak Demand on Generation................................................................. 10
Mitigating Demand Using Building Design and Technologies.................................... 12
Net Zero Energy Homes ............................................................................................... 15
Chapter Three: Defining the Baseline and Proposed Measures........................................ 18
Simulation Tool ............................................................................................................ 18
Energy Efficiency Measures......................................................................................... 20
High Efficiency Air Conditioner .............................................................................. 21
Evaporative Cooling ................................................................................................. 21
Increased Insulation .................................................................................................. 22
High Performance Windows..................................................................................... 22
Window Shading....................................................................................................... 22
High Efficiency Lighting .......................................................................................... 23
Thermal Mass............................................................................................................ 24
Orientation ................................................................................................................ 24
Photovoltaic System...................................................................................................... 25
Lifecycle Costs.............................................................................................................. 27
Chapter Four: Energy Simulation Methodology............................................................... 31
Chapter Five: Hourly Simulation Results......................................................................... 33
Weather......................................................................................................................... 33
Baseline......................................................................................................................... 37
Parametric Analysis ...................................................................................................... 41
Photovoltaics................................................................................................................. 49
Zero Net Peak Demand................................................................................................. 54
Life Cycle Costs............................................................................................................ 57
Chapter Six: Evaluating Zero Peak Demand Performance............................................... 60
Weather Conditions ...................................................................................................... 60
v
Baseline Energy Performance....................................................................................... 63
Parametric Analysis ...................................................................................................... 65
PV System Orientation ................................................................................................. 67
Zero Net Peak Demand................................................................................................. 69
Lifecycle Cost Assessment ........................................................................................... 72
Chapter Seven: Implications for Building Design............................................................ 75
Chapter Eight: Areas for Future Research........................................................................ 79
Glossary ............................................................................................................................ 83
Bibliography ..................................................................................................................... 85
Appendix A: DEER Building Assumptions ..................................................................... 89
Appendix B: Calculation of Lighting Power .................................................................... 91
Appendix C: Baseline eQuest Input File .......................................................................... 92

vi
List of Tables

Table 1: Sun Angle Tilt and Azimuth............................................................................... 25
Table 2: PV Module Characteristics................................................................................. 26
Table 3: Electricity Tariff Detail....................................................................................... 28
Table 4: Life Cycle Cost Assumptions ............................................................................. 30
Table 5: Hourly Weather Characteristics During Peak Period ......................................... 35
Table 6: Comparison of TMY2 and SCE Weather Station Temperatures........................ 37
Table 7: Baseline Annual Electricity Consumption and Peak Demand ........................... 38
Table 8: Hour of Peak Demand by End-Use .................................................................... 40
Table 9: Parametric Results for Package 1 Measures....................................................... 44
Table 10: Parametric Results for Package 2 Measures..................................................... 47
Table 11: Summary of Peak Generation and Production from 2.4kW PV System .......... 53
Table 12: Relative Power and Energy Production by PV Orientation.............................. 53
Table 13: Summary of PV System Required for DX Cooled Homes............................... 54
Table 14: Net Present Value Analysis of Alternatives ..................................................... 58
Table 15: Installed Price of PV Necessary to Achieve NPV=0........................................ 58
vii

List of Figures

Figure 1 Growth in California Residential Electricity Usage 6
Figure 2: California Electricity Use by Sector 7
Figure 3: Southern California Edison Load vs Temperature 8
Figure 4: Five Year Electricity Outlook - CA ISO SP26 9
Figure 5: Levelized Avoided Cost by Month and Hour ($/MWh) 11
Figure 6: Time Dependant Valuation Variation 15
Figure 7: DEER 2-Story Residential Prototype 19
Figure 8: Percentage of Lighting Fixtures During the Day 24
Figure 9: Electricity Tariffs by Hour 29
Figure 10: Amount of Clouding During Aug 12 - 14 33
Figure 11: Temperature and Relative Humidity for August 12 - 14 34
Figure 12: Comparison of Hourly Temperatures for May Through September 36
Figure 13: Contribution to Peak Demand by End-Use, August 13
th
at 5PM 38
Figure 14: Contribution to Annual Electrical Consumption by End-Use 39
Figure 15: Hourly Demand by End-Use 40
Figure 16: Sensible Heat Entering Conditioned Area at 3PM on August 13 41
Figure 17: Cooling Capacity for Package 1 Measures 42
Figure 18: Hourly Peak Demand Profile for Package 1 Measures on August 13 43
Figure 19: Fan Flow for Package 2 Measures 45
Figure 20: Hourly Demand Profile for Package 2 Measures on August 13 46
Figure 21: Monthly Electric Consumption for Baseline and Proposed Cases 48
viii
Figure 22: Monthly Gas Heating Consumption for Baseline and Proposed Cases 48
Figure 23: Hourly Peak Profile for a 2.4kW PV System with Tilt = 25 Degrees 50
Figure 24: Hourly Peak Profile for a 2.4kW PV System with Tilt = Solar Angle 51
Figure 25: Hourly Peak Profile for a 2.4kW PV System with Tilt = 90 Degrees 52
Figure 26: Zero Net Peak Load Profiles Compared with Baseline 55
Figure 27: Zero Net Peak Demand Compared with Baseline on August 12 56
Figure 28: Zero Net Peak Demand Compared with Baseline on June 1 57
Figure 29: Proposed Tariff Rates on August 13 Required to Achieve NPV = 0 59
Figure 30: Optimum Conditions for Direct Evaporative Cooling 60
Figure 31: Direct Normal Radiation versus Cloud Cover During Peak Period 62

ix

Abstract
Meeting peak electric demand poses a significant challenge to electric utilities in
California. The increased use of air conditioning, driven by high summer temperatures,
is the primary cause of this peak demand. This thesis evaluated strategies for eliminating
peak electric demand in single family residential buildings sited in California climate
zone 10. Alternative building designs were analyzed using eQuest to determine the
impact of different energy efficiency measures and rooftop photovoltaics on peak
demand. The simulation results revealed the hourly peak demand between 2 and 5pm
during the hottest three day period contained in the TMY weather data for California
climate zone 10. Based on these results it was concluded that zero electric peak demand
designs are technically achievable. A life cycle cost analysis indicated that these
buildings are not yet cost effective and the net present value is highly sensitive to
electricity tariffs and installed photovoltaic system costs. Zero peak demand residential
buildings represent a key strategy in the effort to address California’s grid congestion and
significantly reduce the environmental impacts of peak electrical generation.
1
Chapter One: Introduction
Peak residential electric demand imposes a growing challenge to the reliability of
California’s electric generation grid. The use of air conditioning compressors to cool a
growing number of homes during hot summer afternoons creates a rapidly rising level of
electric demand that often places an impossible burden on the current network of
generation facilities. This situation worsens each year given the state’s growing
population, increasing residential development in hot inland locations and a trend toward
constructing larger single family residential buildings. The use of generation capacity
which is tapped only during times of high summer peak demand is extremely expensive
and therefore unattractive to utilities. The primary opportunity for addressing this
problem lies in the construction of residential buildings with reduced summer peak
demand.

The purpose of this thesis is to evaluate strategies for achieving zero peak electrical
demand in a single family residential building in California climate zone 10. Eliminating
peak demand represents a highly attractive goal for electric utilities in California
struggling to maintain sufficient generation capacity during periods of sustained high
summer temperatures. The analysis used in this thesis is based on a residential model
developed by the California Energy Commission for use in the DOE2.2 hourly simulation
engine known as DEER (Database for Energy Efficiency Resources). Alternative energy
efficiency measures were applied to the DEER residential model to determine the impact
on peak demand. These measures were first simulated separately then those which
2
significantly reduced peak demand were simulated as a package. The addition of a
photovoltaic (PV) system was used to eliminate the remaining demand. The PV system
was simulated in a number of different orientations to determine the impact on generation.
The energy efficiency measures and PV systems were then simulated together to allow
sizing of the PV system so that peak demand was reduced to zero. The life cycle cost of
each of the energy efficiency/PV systems selected was also analyzed.

Throughout this thesis peak demand refers specifically to the demand during 2pm to 5pm
on August 12, 13 and 14. This nine hour period is defined by the California Energy
Commission as the peak demand period for climate zone 10 and is based on the TMY2
weather data file.

Chapter 2 discusses the peak demand crisis and why it currently represents such a
challenge to electric utilities in California. Electricity consumption in California
continues to grow and residential buildings represent a significant proportion of this
growth. High summer temperatures create short high periods of demand with the total
load strongly correlated with temperature. Growing demand is projected to exceed
available generation capacity under some scenarios as early as 2010. Meeting peak
demand is already extremely expensive for electric utilities due to the short duration of
the peak periods and the high cost of maintaining peak generation capacity. Energy
efficient technologies can be very effective at reducing peak demand or shifting demand
to off-peak periods. PV systems also have a significant role in reducing peak demand
3
given that periods of high temperatures are also usually accompanied by high levels of
solar insolation.

Chapter 3 describes the baseline and proposed assumptions used in the analysis of zero
peak residential buildings. The hourly simulation tool, eQuest is described along with the
DEER single family residential model used at a baseline in the analysis. The
assumptions used to define all the energy elements of the model are listed including
building envelope, air conditioning and internal loads. Each of the energy efficiency
measures used in the analysis is described along with the assumptions used to define each
measure. Also included is a description of the PV systems used and the approach to
simulation. Life cycle cost assumptions are based on utility tariffs and first costs. The
overall methodology for conducting the simulation process is also discussed.

Chapter 4 outlines the methodology used to conduct the simulations used in this analysis.
The first step was to generate the simulation results for the baseline building against
which other proposed measures could be compared. The next step was to conduct
parametric modeling of different energy efficiency measures to determine the impact on
peak demand. Then PV systems were simulated to determine the size and orientation
necessary to eliminate the remaining peak demand. Finally a life cycle cost assessment
was performed.

4
Chapter 5 contains detailed results generated at each step in the analysis. Each eQuest
simulation run generates 8,760 hours of simulation data. The focus of the data collection
was on the hourly performance of the residential building during the peak period.

Chapter 6 contains a discussion of the results and implications for achieving zero
residential peak performance. The weather data used in the analysis is reviewed to
determine its relevance as a predictor of future peak demand. The impact of each of the
energy efficiency measures on the peak load profile is discussed relative to baseline peak
demand. The total potential reduction in peak demand as a result of the measure
packages is also compared with the baseline peak demand. The sizing and orientation of
the PV system necessary to achieve zero peak demand is discussed along with the
resultant impact on life cycle costs.

Chapter 7 contains the conclusions following from the discussion in the earlier chapter.
Statements are made about the value of energy efficiency measures and PV systems as a
means of reducing peak demand.

Chapter 8 contains recommendations for future work which would enhance and build
upon the work done in this thesis. By necessity this thesis was limited in its geographic
scope and by the capabilities of existing simulation tools. More research is needed on
which to effectively base electric utility actions, building designs and public policy.

5

Chapter Two: The Peak Demand Crisis
Electrical Consumption in California
The most common metrics used by utilities in measuring electricity consumption are
annual energy consumption measured in kilowatt hours (kWh) and peak load (kW). Peak
demand, also referred to as peak load, is the instantaneous power consumption and can be
measured at the point of end-use or at other points over the distribution system.
Maintaining enough grid capacity to meet peak electrical demand is one of the most
significant challenges to California’s electricity grid. On July 24
th
, 2006 peak demand in
California reached 50.2 GW which was a record for the State. Increasing development
and population growth continue to place upward pressure on the grid. Forecasts indicate
that while electrical consumption will grow at an average annual rate of 1.15-1.49% per
year from 2004 – 2016, peak demand will grow by 1.4 – 1.75% annually during the same
time period. (California Energy Commission, 2006d, p1-6). Given the significant
economic and political repercussions of grid failure the issue of peak demand is clearly
emerging as a key challenge for California.

California’s electrical energy consumption continues to rise each year. On average in the
state consumed 6,732 kWh per capita in 2003 (California Energy Commission, 2006g),
considerably lower than all other states in the U.S. This per capita energy consumption is
higher than the European average of 5,765 and much higher than the world average of
2,436 (International Energy Agency, 2006). Electricity usage continues to grow driven
6
by an ever increasing population and expanding development. In 1980 Californians used
52,082 million kWh compared with 84,527 million kWh in 2005 and has grown by 2 to
6% per year (See Figure 1, California Energy Commission, 2005a). Usage growth has
grown steadily except for years such as 2001 which, due to the California energy crises,
was impacted by rolling blackouts and aggressive promotion of energy conservation
measures.

50,000
55,000
60,000
65,000
70,000
75,000
80,000
85,000
90,000
1980 1985 1990 1995 2000 2005
Total California Residential Electricity Consumption
(million kWh)
-8%
-6%
-4%
-2%
0%
2%
4%
6%
8%
Annual Growth in Residential Electricity Use

Figure 1 Growth in California Residential Electricity Usage

7
The residential sector is the largest consumer of electricity in California and used 84,527
GWh in 2005 or 32% of the states total usage (See Figure 2, California Energy
Commission, 2005a).

Figure 2: California Electricity Use by Sector

Electricity demand is highly temperature dependant in California due the increasing use
of air conditioners as temperatures rise. Research on 2004 load data by the California
Energy Commission (2005e, p. 20) indicates that for every one degree in temperature rise
8
during the summer period, the demand in Southern California Edison territory increases
by 317 MW. (See Figure 3.)

Figure 3: Southern California Edison Load vs Temperature

Projections of electricity needs through 2010 indicate that the gap between available
generation and demand will continue to shrink and the risk of insufficient supply during
summer peak periods will increase. The CPUC requires that utilities maintain 15%
spinning reserves (surplus available generation capacity) and failure to maintain this
percentage can trigger multi-stage electricity alerts. For planning purposes forecasts are
made of electricity demand for 1-in-2 (average) and 1-in-10 (adverse) summer conditions.
(See Figure 4, California Energy Commission 2006a, p. 35). These forecasts indicate
that under adverse conditions the state will not have enough supply to meet adverse
9
conditions as early as 2007. The growth in statewide electricity demand in Southern
California (referred to as SP26 by the California Independent System Operator) will
require an additional 1754 MW of capacity by 2010 to achieve a 7% operating margin
under adverse conditions (California Energy Commission, 2006, p. 35). Not included in
these planning estimates is the impact of global warming which some may argue is
already causing higher summer temperatures. Over the coming decades global warming
could become an increasingly significant driver of demand as the frequency and
magnitude of high temperature summer days increase and lead to increased air
conditioning usage.

Figure 4: Five Year Electricity Outlook - CA ISO SP26

10
The Impact of Peak Demand on Generation
While most electrical generation plants are designed to deliver a relatively constant level
of power, meeting peak demand requires generation technologies that can ramp up and
down quickly. This capability is not a good match for conventional generation
technologies which are designed to operate a relatively constant level of output to
maximize efficiency.

One problem with meeting peak demand is that most new gas-fired power
plants are combined-cycle units designed to run at high load factors
where they are most efficient and can generate enough revenue to recoup
investments. Combined-cycle plants also have less capability to ramp up
and down to meet peak demand than the older steam boiler units, which
make up the majority of California’s fleet of power plants. While some
utilities have invested in simple-cycle peaking plants that run just a few
hours per year, most of the state’s new power plants are combined-cycle
and are not well matched with swings in system demand. California must
quickly and thoughtfully craft solutions for meeting this increasingly
“peaky” demand. (California Energy Commission, 2005c, p49)

Given the need for expensive generation capacity to meet peak demand it follows that the
cost of providing electrical energy varies with time. Levelized avoided costs based on
utility generation data for California indicate that a kWh saved at 4am during August is
worth $61while a Megawatt hour saved at 4pm is worth $222 (See Figure 5, Energy and
Environmental Economics, 2006). Mapping these costs throughout the year
indicates that the summer peak period represents the most expensive electrical
energy.
11
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
1
2
3
4
5
6
7
8
9
10
11
12
Hour
Month
$- - $50 $50 - $100 $100 - $150 $150 - $200 $200 - $250

Figure 5: Levelized Avoided Cost by Month and Hour ($/MWh)
To address the difficult in maintaining electrical supply in the face of growing demand
the State of California has developed a loading order. The loading order establishes
priorities for energy policies and is defined as energy efficiency, demand response,
renewables and distributed generation (California Energy Commission, 2005b). Each of
these priorities are considered energy resources which should be given a greater priority
than the addition of conventional fossil fueled generation. Energy efficiency and demand
response are the most important of these priorities due to market acceptance and more
favorable economics.
12
Mitigating Demand Using Building Design and Technologies
Managing peak demand is a priority for electric utilities as they seek to lower operating
costs and reduce the risk of system outages. The strategies use to affect peak demand
include the following (Koomey, 2002, p. 5):

• Load reducing strategies - Dropping of load through the use of controls or behavioral
changes.
• Load shifting strategies - Use of energy storage or smart controls to move load to off
peak hours.
• High efficiency equipment - Use of equipment which uses less energy but achieves the
same level of output.
• Fuel switching - Use of natural gas or other fuels as a substitute for electricity.
• On site generation - Use of power production equipment at the building site.

Given that peak demand in California is primarily driven by the use of air conditioning,
any strategy which reduces the internal heat gain or shifts load to non-peak periods in a
residential building will reduce the peak load on the air conditioning system. These
strategies can be classified as either passive or active strategies. Passive strategies are
those which utilize natural forces such as wind or shading. Active strategies are those
which use systems that require energy such as DX cooling.

Passive Strategies
• Low solar heat gain glazing
13
• Window shading devices
• Thermal mass
• Building Orientation
• Insulation

Active Strategies
• High efficiency lighting
• High efficiency plug load equipment
• High efficiency air conditioning systems
• Off peak ice storage

One promising strategy for reducing peak demand is pre-cooling using the building’s
thermal mass. Pre-cooling can be accomplished using night flushing or thermostat
temperature reset. Night flushing uses either an economizer cycle or natural ventilation
to draw in cool night air and cool the building’s mass. Night time temperatures need to
be low for this strategy to work and the results vary depending on the amount and type of
thermal mass in the building as well as the pattern of airflow throughout the building.
Thermostat temperature reset uses the building’s existing HVAC system but varies the
thermostat set point and operating times. Pre-cooling and zonal temperature reset
strategies in a conventional commercial building have been demonstrated to shift 80 –
100% of peak cooling demand to off peak periods (Xu et al, 2004, p. 9). Pre cooling
takes place at around 70 deg. F. at the lower end of the comfort range while peak period
temperatures are around 76 – 78 deg. F. Some comfort issues can occur when these kinds
14
of temperature swings are allowed but research has revealed that occupant complaints can
be minimized with careful implementation (Xu et al, 2005, p. 29). In order to avoid a
potential rebound in demand for short periods of time it has been found that an
exponential zone temperature set point trajectory is preferred over a single step
temperature reset between off peak and on peak (Xu et al, 2005, p. 29).

In California the building code applies a time varying valuation mechanism to the
expected energy consumption of a new building. Known as Time Dependant Valuation
(TDV), the electrical energy used is weighted based on the location and type of building
(See Figure 6, Pacific Gas and Electric, 2002). Energy consumed during peak periods are
given a higher weighting that those during off peak periods. Two buildings which
consume the same annual amount electrical energy might consume very different
amounts of TDV energy depending on their usage profiles. While TDV weighting
factors include generation costs, they also take into account other factors such as
environmental impacts and transmission and distribution losses. TDV provides a means
to capture the benefits of mitigating peak demand.

15

Figure 6: Time Dependant Valuation Variation
The TDV multiplier consists of a set of 8,760 values which are applied to each hours
electrical energy use during a compliance simulation run for a building. At 4pm on
August 13
th
in climate zone 10 the TDV multiplier is 62.87 kBtu/kWh which means that
for every 1 watt used in the building the TDV impact is 62.87 Btu or 18.43 watts.

Net Zero Energy Homes
There is increasing reference throughout the residential building community net zero
energy homes. The actual definition of what defines one of these homes varies
significantly and has resulted in some confusion. In many cases a net zero energy home
is actually a low energy home which still consumes energy. The definition of a net zero
energy home can be found in the Dictionary of Sustainable Management.

16
A home employing site-appropriate passive solar design, site-appropriate
renewable energy products, and proven energy efficiency/conservation
technologies and practices, resulting in an annual contribution to the electricity
grid that is equal to or greater than the amount of power the home uses from the
grid (September 29, 2007).

This definition is based on measurement of energy use at the site meter and does not
consider the energy losses involved in the extraction, refining and transportation of
carbon based fuels or the generation, transmission and distribution of electricity.

All net zero energy homes require the use of a PV system to offset essential energy uses
which cannot be eliminated through the energy efficiency or conservation. Many single
family residential buildings have the roof area to accommodate PV and installation is
relatively straightforward. There continues to be some concern about the aesthetics of
rooftop PV but this is becoming less of an issue given expanding array of PV module
products tailored for the residential roofing market. State and federal governments are
now playing instrumental role in building a market for on-site PV, residential and non-
residential through the use of rebates and tax credits. In recent years there has been a
particularly strong effort in California to encourage the use of PV in residential
applications. The CEC’s Emerging Renewables program which rebates a portion of the
cost of installing a PV system is one such example. As of May 2005 the program had
rebated 2700 PV systems for new homes since it was launched in 1998 (Barbose, G.,
Wiser, R., Bolinger, M., 2006). This program was replaced in the beginning in 2007 with
the New Solar Homes Program which will continue the rebate program for residential PV
installations. The rebate level was set initially at $2.60/watt and will be lowered over
17
time based as certain installation capacity targets are reached. (California Energy
Commission 2006h, p15)

Results from a recent zero energy home demonstration project in Sacramento indicate
that the potential impact of energy efficiency combined with PV on peak demand may be
large. The project consisted of 95 near zero energy homes each of which included an
array of energy efficiency features along with a 2kW (AC) rooftop photovoltaic system.
During the July 2005 monitoring results revealed that the new homes had reduced peak
demand between 12pm – 7pm by 73% (Keesee, M, Hammon, Rob, 2006). This was
despite the fact that these homes had been designed to reduce annual energy use rather
than peak demand. Results like these have indicated that a zero peak residential
community might be more achievable than a zero energy residential community in the
near future. The Sacramento Municipal Utility District has recently launched an
initiative to see if zero peak homes are technically and practically feasible (Ceniceros, B
and Vincent, V., 2006).

All the factors discussed above underline the importance of reducing peak residential
demand and provide a snapshot of current efforts mitigate the impact of peak demand on
the electrical grid. Consideration of the peak demand impact of buildings deserves the
same level of consideration as overall energy use. In response architects and engineers
will need to increase their awareness of strategies for addressing peak demand in building
design. This thesis addresses this need directly by evaluating strategies for reducing peak
demand in residential buildings.
18
Chapter Three: Defining the Baseline and Proposed Measures
As discussed earlier, electrical generation capacity must be able to accommodate peak
load to avoid blackout conditions. California is currently grappling with ways to
accommodate rapidly growing peak demand during a time of limited generating capacity
and significant difficulties with increasing that capacity. The highest peak demand
typically occurs during hot summer days when air conditioning loads are at their highest.
Residential buildings are significant contributors to this peak condition, especially in hot
dry climate zones. This purpose of this thesis is to evaluate strategies for achieving zero
peak residential electrical demand.
Simulation Tool
The primary tool used in this analysis is eQuest, which consists of a graphical interface
overlaid on the DOE 2.2 simulation engine. eQuest is one of the primary whole-building
energy simulation tools used in California and can be used to determine compliance with
California’s Title 24 Building Energy Code. The version of eQuest used is 3.56 which is
the latest publicly available version (J. Hirsch, 2007). The DOE 2.2 engine is an
enhancement to DOE 2.1E engine previously developed by the Department of Energy
and used in many of today’s simulation models. The weather file used in the simulation
was the TMY2 binary weather file for climate climate zone 10.

The residential building which will be used as the baseline is the Database of Energy
Efficient Resources (DEER) residential code baseline prototype. The California Public
Utilities Commission and the state’s Investor Owned Utilities developed the DEER
19
database to establish a common set of assumptions for evaluating energy efficiency
measures. (California Energy Commission, 2005d). The DEER database includes data on
36 different measures along with different building baseline prototypes and can be found
at www.energy.ca.gov/deer. The residential single family prototype consists of four
buildings, two 2-story and two 1-story and is designed to be very representative of
California construction however only the 2-story building was used in this analysis. The
vintage of the prototype selected was 2005 and is minimally compliant with the Title 24
Building Code.

Figure 7: DEER 2-Story Residential Prototype

The DEER residential prototype is intended to model as realistically as possible, the
energy use profiles of an average house. For this reason some parameters used in the
model such as occupancy schedules are based on average values rather than a specific
number of occupants. This approach enables the results to be considered as
representative across a population of 2005 vintage residential buildings located in the
same climate zone. No attempt will be made to account for the diversification of load
profiles across the building population.
20

The baseline prototype is made up of a detailed list of pre-defined parameters which
define a simulation model for eQuest. (See Appendix A.) The detailed assumptions on
which these schedules are based has not been published however these values have been
deemed representative by the California Energy Commission.

The approach used to estimate peak demand will be similar to that used in DEER. The
CPUC defines peak as “the average grid level impact for the measure from 2 p.m. to 5
p.m. during the three consecutive weekday period containing the weekday with the
hottest temperature of the year.” (California Public Utilities Commission, 2006.) Rather
than assume that the residential equipment is cycling, this analysis will assume that all
equipment is operated continuously and therefore runtime will not be taken into
consideration. This differs from the DEER approach which takes equipment cycling into
account for residential measures. However it is consistent with the approach used for
non-residential measures. For climate zone 10 the peak demand period defined in DEER
is August 12 – 14.

Energy Efficiency Measures
Selection of appropriate measures for analysis was limited to those measures which had
the potential to reduce peak electrical demand and which could be effectively simulated
using DOE 2.2. Many promising measures were already defined in DEER, however
others needed to be manually created. A number of energy efficiency measures were
21
excluded from this analysis. Title 24 requirements already include a high level of
stringency beyond which further energy benefits are very difficult to achieve. Where
measures were expected to provide very small or negligible benefits beyond Title 24 they
were not analyzed. In some cases, measures were excluded as they had no opportunity to
impact peak electric loads.
High Efficiency Air Conditioner
The Seasonal Energy Efficiency Ratio (SEER) of the baseline split-system direct
expansion air conditioning unit was increased from 10 to 15. SEER is defined as the
cooling output during normal annual operation divided by the electrical energy input. Air
conditioner manufacturers are required to achieve minimum SEER ratings under Federal
regulation. Ratings are achieved under defined conditions and are published by the
manufacturer. A SEER 15 unit is approximately 50% more efficient than a SEER 10 unit
and is already commercially available. The performance characteristics of the SEER 15
unit were taken directly from DEER measure D03-463 (California Energy Commission,
2005d).
Evaporative Cooling
The baseline split-system direct expansion air conditioning unit was replaced with an
evaporative cooling unit. Direct and direct-indirect (two-stage) evaporative units were
simulated as separate measures. Performance characteristics were taken from DEER
measures D03-405 for the direct unit and D03-407 for the direct-indirect unit (California
Energy Commission, 2005d). The high humidity levels that can be produced by
evaporative systems are not simulated in DOE2.2 and were therefore ignored.
22
Increased Insulation
The resistance of wall and ceiling insulation was increased for exterior walls enclosing
conditioned spaces. For exterior walls the baseline U-value was reduced from 0.055 to
0.043 Btu/hr-ft2-F based on the use of 2 inch by 6 inch studs, R-21 batts and R-5 rigid
insulation. Performance characteristics for this wall insulation measure were taken from
DEER measure D03-437 (California Energy Commission, 2005d). For ceiling insulation
the baseline U-value of the attic floor was reduced from 0.027 to 0.021 based on the use
of R-49 insulation batts. Performance characteristics for this ceiling insulation measure
were taken from DEER measure D03-424 (California Energy Commission, 2005d).
High Performance Windows
All windows on the east, south and west facades were upgraded to triple low-e glazing
with a U factor (glass plus frame) of 0.25 and a SHGC of 0.35. The baseline glazing had
a U factor of 0.57 and a SHGC of 0.40. Performance characteristics for this high
performance windows measure were taken from DEER measure D03-449 (California
Energy Commission, 2005d).
Window Shading
External shading devices were installed on all windows on the east, south and west
windows. South windows were treated with an overhang 3 feet in depth and the same
width as the window. The same overhang was used on the east and west windows but
side fins 3 feet in depth were also added.

23
High Efficiency Lighting
All interior incandescent lamps were upgraded to high efficiency compact fluorescent.
Title 24’s prescriptive requirements for lighting are based on lamp efficacy rather than
lighting power density as is the case for non-residential buildings. Without this code
requirement it is not possible to calculate the total lighting power for a code compliant
house. Lighting needed to be added to the code baseline prototype in order to evaluate
the impact on peak demand of high efficacy lamps. An estimate of lighting power was
constructed based on California specific lighting survey data collected by the California
Energy Commission and KEMA Inc. (See Appendix B.)

The code baseline assumes incandescent lamps are used in all rooms except the kitchen
where fluorescent lamps are required by Title 24. In the high efficiency measure all
lamps are assumed to be fluorescent.

A lighting schedule was also developed to indicate what portion of the installed lighting
would be on at a particular hour of the day. In reality, lighting schedules vary seasonally
but this level of data could not be located. As an alternative an average annual lighting
schedule was used based on research conducted by the California Energy Commission.
The resultant profile potentially overestimates lighting use during the summer months
when daylight is available until late in the evening. (See Figure 8.)

24
0
5
10
15
20
25
30
0 5 10 15 20 25
Time (hrs)
Fixtures On (%)

Figure 8: Percentage of Lighting Fixtures During the Day
Thermal Mass
Thermal mass was included as a measure due to its potential to shift loads to off-peak
periods of the day. The thermal mass measure used in this analysis was the use of open
concrete slab floors. The DEER residential prototype included a concrete slab on the first
story and a timber subfloor on the second story. The measure analyzed was to create an
open concrete slab floor on the first and second stories. The default four inch slab floor
default parameters provided in eQuest was selected to describe the floor.
Orientation
The impact of exposure was also tested. Building orientation was changed from
orientation neutral to an east-west axis orientation. The DEER residential prototype is
25
designed to be orientation neutral with symmetrical facades and half of the buildings
rotated by ninety degrees. To remove this neutrality two buildings were rotated by 90
degrees. A parametric analysis using eQuest was conducted to determine the orientation
which minimized the peak demand. The four-building model was simulated for all
orientations between an azimuth of 0 and 90 degrees in increments of 10 degrees.
Photovoltaic System
There are a number of ways in which PV systems can be oriented on a residential
building. For this analysis three orientations were considered:

1. Tilt at roof pitch (25 degrees) and placement on roof
2. Tilt at sun angle and placement on roof
3. Tilt at vertical and placement on western facade

A tracking PV system was not considered as no capability for simulating a tracking
system is currently available in eQuest. Each of the orientations was simulated at
different azimuths in accordance with the sun angle. (See Table 1.) The sun angle was
calculated using Solaris version 2.1 released in 1988 using a latitude of 33.9 degrees.
Table 1: Sun Angle Tilt and Azimuth
Time
Tilt
(degrees)
Azimuth
(degrees)
12pm 19.8 180
1pm 23.7 218.5
2pm 33.6 241.2
3pm 45.1 255.3
4pm 57.4 265.4
5pm 69.9 273.8
6pm 82 282.1

26

The PV module used in the analysis was the SunPower SPR 220 which uses the high
efficiency A-300 single crystal silicon solar cell and achieves an overall module
efficiency of 17.7%. (See Table 2.)

Table 2: PV Module Characteristics
Dimensions 61.39” * 31.42”
Open Circuit Voltage 48.3Volts
Open Circuit Voltage Temperature Coefficient -0.1368Volts/degree C
Short Circuit Current 5.95amps
Short Circuit Current Temperature Coefficient 0.00039 1/degree C
Maximum Power Voltage 39.80 Volts
Maximum Power Current 5.53 amps
Temperature difference between front and back of cell (degrees C) 2.0 degree C

The irradiance performance curves used were the defaults provided in eQuest. The
inverter parameters were oversized so the capacity of the inverter would limit module
output. Separate electric meters were defined for each house so usage and generation
could be tracked separately. These meters were simulated under net metering conditions
which allow the meter to run backwards during any hour in which energy generated
exceeds energy consumed. Net metering is a program provided by Southern California
which allows the customer to be billed only for the net difference between the amount of
electricity produced and the amount of electricity consumed in a billing period. Any
27
credits are banked over a 12-month billing period. Net metering requires the use of a bi-
directional meter which can spin backward when generation exceeds demand.
Lifecycle Costs

The calculation of lifecycle costs was based on the incremental first costs of the energy
efficiency measures and the PV system as well as the lifecycle energy costs. External
environmental impacts were not included in this analysis. The tariffs used to calculate
electric bills were based on residential rate options provided by Southern California
Edison. The two rates selected for this analysis were Schedule D and Schedule TOU-D-1.
(Southern California Edison, 2006b.) Schedule D assesses different charges based on
blocks of average daily usage. The baseline allocation for climate zone 10 is 10.2 kWh
per day. (Southern California Edison, 2006b.) Schedule TOU-D-1 contains winter and
summer on and off-peak rates. Summer is defined as June through September and on-
peak hours are 10am – 6pm on weekdays. The energy rate is made up of generation,
transmission and distribution charges along with a daily meter charge. (See Table 3 and
Figure 9.)
28
Table 3: Electricity Tariff Detail
Delivery Service Total*
Utility Retained
Generation
Department of
Water Resources
$/kWh $/kWh $/kWh $/kWh
Baseline 0.066 0.036 0.095 0.131
101-130% of Baseline 0.066 0.063 0.095 0.145
131-200% of Baseline 0.066 0.180 0.095 0.203
201-300% of Baseline 0.066 0.303 0.095 0.265
Over 300% of Baseline 0.066 0.303 0.095 0.265
Meter charge per day 0.029
Delivery Service Total*
Utility Retained
Generation
Department of
Water Resources
$/kWh $/kWh $/kWh $/kWh
Summer on-peak 0.088 0.541 0.095 0.406
Summer off-peak 0.088 0.053 0.095 0.162
Winter on-peak 0.088 0.099 0.095 0.185
Winter off-peak 0.088 0.036 0.095 0.153
Meter charge per day 0.029
TOU meter charge per day 0.08
* Assumes 50% of energy from Utility Retained Generation and 50% from Department of Water Resources
Schedule D
Schedule TOU-D-1
Generation
Generation

During simulation both tariffs were calculated and the results evaluated to see which
tariff provided the lowest annual utility bill.
29
0.1
0.15
0.2
0.25
0.3
0.35
0.4
0.45
0 5 10 15 20 25
Average Daily Energy Use (kWh)
Electricity Cost ($/kWh)
Schedule D Tariff
TOU D1 Summer Off-Peak Tariff (6pm - 10am)
TOU D1 Winter On-Peak Tariff (10am - 6pm)
TOU D1 Winter Off-Peak Tariff (6pm - 10am)
TOU D1 Summer On-Peak Tariff (10am - 6pm)
1
2
3
4

Figure 9: Electricity Tariffs by Hour

Incremental equipment costs were determined for each energy efficiency measure and
installed costs estimated for the PV system. (See Table 4.)

30
Table 4: Life Cycle Cost Assumptions
Description Incremental Cost Measure Life Assumptions
Fluorescent
lighting
$3.50 / lamp 8 years Compact fluorescent lamps retail for
approximately $4 and incandescent lamps retail
for approximately $0.50. (Bulbs.com, 2007.)
Measure life is based on 4,000 hours lamp life
and operation of 500 hours per year.

Exterior Canvas
Awnings
$278/window 5 years Canvas awning, 3’ wide with a 32’ projection.
Awnings - $278/window 32” projection, 3’
wide, valiant canvas awning.
(cheapawnings.com, 2007.)

Low SHGC
glazing
$4.33/100sqft of
window
20 years DEER measure D03-452 “U-0.35/SHGC-0.32
window”

SEER 15 Air
Conditioner
$277.86/ton of
cooling
18 years DEER measure D03-463 “15SEER Residential
Air Conditioner”

Direct-Indirect
Evaporative
Cooler
$713.83/1000sqft 15 years DEER measure D03-407 “Indirect Evaporative
Cooler”
4” Concrete Slab
Floor
$4.24/sqft 50 years Based on an average of a cost range of 3.96 –
4.51 dollars/sqft (California State Board of
Equalization, 2007, p 195)

PV system $5.94/watt(DC) 20 years (California Energy Commission, 2005e)

31
Chapter Four: Energy Simulation Methodology
A four step process was used to derive the optimum package of energy efficiency
measures and PV system configuration required to eliminate peak demand.

1. Create modified DEER baseline building: All aspects of the DEER residential
prototype will be retained for use as a baseline. The only change will be the
addition of lighting energy and a lighting use profile, both of which are not
included in this prototype. To simulate the impact of building orientation a 2-
building prototype will be used in some cases as the 4-building prototype is
orientation neutral.

2. Conduct parametric modeling: All energy efficiency measures which can be
realistically simulated in DOE 2.2 and have the potential to impact peak electrical
demand will be evaluated. The following procedure will be used to select an
optimum measure package:

a. During the first phase of the simulation measures will be evaluated
separately to the determine peak load profiles. Measures will be grouped
and ranked based on type (envelope, internal load, HVAC) and peak load
impact (peak kW, peak kWh). 24-hr load profiles will also be generated
for each measure.

32
b. A series of measure packages will be constructed based on the sets of
measures which appear most promising based on peak demand reduction
potential. Parametric analysis will be used to account for and to reveal
interactive effects so these measure packages can be fine tuned.

3. PV Optimization: Alternative PV systems and configurations will be simulated
to determine the correct performance and sizing necessary to eliminate any
remaining peak demand. Three different PV orientations will be evaluated; (1)
Tilted at roof pitch (25 degrees), (2) Oriented at the solar angle and (3) on the
western façade.

4. Life Cycle Costing: First costs and electric utility tariffs will be incorporated into
the model to determine the full life cycle costs associated with the energy
efficiency measures and the PV.

The analyses used in this thesis rely on simulation tools and assumptions which have
been extensively tested for use in California and rely on assumptions which, in almost all
cases, have been validated by the State of California. Although the results are based on
simulations and not field measurements, the differences are unlikely to impact the
conclusions drawn.
33
Chapter Five: Hourly Simulation Results
This chapter contains the simulation results for the baseline, energy efficiency measures,
photovoltaic systems and the final optimized buildings. All results were generated using
eQuest using the methodology described in the previous chapter. Additional detail is
presented in the Appendices.
Weather
The amount of clouding in Figure 10 and the hourly wet bulb, dry bulb and relative
humidity for the peak period August 12 – 14 is shown in Figure 11.

Figure 10: Amount of Clouding During Aug 12 - 14

34

Figure 11: Temperature and Relative Humidity for August 12 - 14
The hourly weather characteristics during the peak period of 2pm – 5pm are shown in
Table 5 .

35
Table 5: Hourly Weather Characteristics During Peak Period
Dry
Bulb
(F)
Wet
Bulb (F)
Relative
Humidity
(%)
Wind
Speed
(ft/sec)
Wind
Direction
(degrees)
Cloud
Amount
(1-10)
August 12

2-3pm 98 66 16.4 10.1
269 0
3-4pm 98 66 16.4 16.9
228 0
4-5pm 99 68 18.9 16.9
228 0

August 13

2-3pm 102 68 15.7 13.5
228 0
3-4pm 104 67 12.2 16.9
228 0
4-5pm 103 67 13.1 13.5
207 0

August 14

2-3pm 103 72 21.5 10.1
248 7
3-4pm 101 71 22.1 11.8
207 8
4-5pm 96 70 26.7 13.5
207 7

Hourly temperatures for 2 Southern California Edison weather stations located in climate
zone 10 were compared with the TMY2 hourly temperatures for climate zone 10 in
Figure 12.
36

Figure 12: Comparison of Hourly Temperatures for May Through September

The maximum annual temperature for each year of the Southern California Edison
weather stations and the TMY2 weather data is shown sorted in descending order in
Table 6.

37
Table 6: Comparison of TMY2 and SCE Weather Station Temperatures
Weather Station Year Maximum
(In descending order)
(Degrees F)
Date Time
SCE 12.1 2006 112.4 22-Jul 1PM
SCE 12.1 2006 110.8 22-Jul 4PM
SCE 12.1 2002 107.5 9-Jul 2PM
SCE 12.1 2003 105.2 14-Aug 4PM
SCE 12.1 2002 104.9 1-Sep 2PM
SCE 12.1 2004 104.3 10-Aug 2PM
SCE 12.1 2005 104.1 14-Jul 2PM
SCE 12.1 2005 104.1 28-Aug 3PM
TMY2 CZ10 1960-1990 104 10-Jul 2PM
SCE 12.1 2001 103.7 7-Aug 3PM
SCE 12.1 2003 103.4 21-Sep 4PM
SCE 12.1 2001 101.9 24-Sep 4PM
SCE 12.1 2004 101.6 10-Aug 3PM
SCE 12.1 2005 101.2 19-Jul 4PM

Baseline
The DEER residential prototype was used as the baseline for the analysis of the energy
efficiency measures. The annual electrical energy consumption for each building is
shown in Table 7. The peak demand was calculated by averaging the demand between 2
and 5pm over August 12 – 14.

38
Table 7: Baseline Annual Electricity Consumption and Peak Demand
Annual
Electricity
Consumption
(kWh)
Peak Demand
(kW)
Cooling
Capacity
(Btu/hr)
Annual
Electric Bill

Orientated with
long axis E-W
8,907 4.52 43,000 $1,593
Orientated with
long axis N-S
9,281 5.02 49,000 $1,688

The four end uses of electrical energy were space cooling, ventilation fans, miscellaneous
equipment, and lighting. A breakdown of the peak demand and energy usage by end use
is shown in Figures 14 and 15.

Figure 13: Contribution to Peak Demand by End-Use, August 13
th
at 5PM
39

Figure 14: Contribution to Annual Electrical Consumption by End-Use

The combined and individual hourly demand profile for August 12-14 is shown in Figure
16.

40

Figure 15: Hourly Demand by End-Use
The time period at which the peak demand occurs for each end-use type is shown in
Table 8.
Table 8: Hour of Peak Demand by End-Use
End-Use Hour of Peak Demand
Lighting 6 – 7PM
Miscellaneous Equipment 8 – 9PM
Cooling 3 – 4PM
Ventilation Fans 4 – 5PM (August 12,13)
3 – 4PM (August 14)
Combined 4 – 5PM

The source of the sensible heat entering the conditioned area on August 13 at 3pm is
shown in Figure 17.
41
-500 0 500 1000 1500 2000 2500 3000 3500 4000
Window Conduction
Wall Conduction
Floor Conduction
Door Conduction
Equipment
Occupants
Glass Solar
Lighting
Infiltration
Cooling Load (Btu/hr)
Top Floor
Ground Floor

Figure 16: Sensible Heat Entering Conditioned Area at 3PM on August 13
Parametric Analysis
Energy efficiency measures were simulated using the residential prototype orientated in
an E-W orientation. A parametric analysis was performed to capture the interactive
effects and quantify the annual energy and peak demand benefits. The cooling system
was sized as small as possible for each measure while still maintaining zero unmet
cooling load hours in the ground and top stories. The first set of parametric results are for
the use of SEER 15 split system cooling (package 1 measures). The cooling system size
for each measure is shown in Figure 18.

42

Figure 17: Cooling Capacity for Package 1 Measures

The hourly demand profile for package 1 measures on August 13 is shown in Figure 19.
43

Figure 18: Hourly Peak Demand Profile for Package 1 Measures on August 13

The incremental and cumulative parametric results for Package 1 measures are shown in
Table 9.

44
Table 9: Parametric Results for Package 1 Measures
Lighting Plug Fans Cooling Total Average
Loads Peak
Demand
(kWh) (kWh) (kWh) (kWh) (kWh) (kW)
Baseline 1645 5372 395 1496 8907 4.5
+ SEER 15 Cooling 1645 5372 260 1399 8676 3.9
+ High Performance Glazing 1645 5372 222 1315 8554 3.6
+ Additional Wall Insulation 1645 5372 204 1249 8469 3.5
+ Additional Ceiling Insulation 1645 5372 191 1206 8414 3.4
+ External Shading 1645 5372 173 1030 8219 3.2
+ High Efficiency Lighting 599 5372 168 960 7098 3.1
+ Open Slab Floors 599 5372 83 409 6463 2.3
+ SEER 15 Cooling 0% 0% 34% 6% 3% 14%
+ High Performance Glazing 0% 0% 15% 6% 1% 6%
+ Additional Wall Insulation 0% 0% 8% 5% 1% 5%
+ Additional Ceiling Insulation 0% 0% 6% 3% 1% 2%
+ External Shading 0% 0% 10% 15% 2% 5%
+ High Efficiency Lighting 64% 0% 3% 7% 14% 3%
+ Open Slab Floors 0% 0% 50% 57% 9% 26%
+ SEER 15 Cooling 0% 0% 34% 6% 3% 14%
+ High Performance Glazing 0% 0% 44% 12% 4% 19%
+ Additional Wall Insulation 0% 0% 48% 17% 5% 23%
+ Additional Ceiling Insulation 0% 0% 52% 19% 6% 25%
+ External Shading 0% 0% 56% 31% 8% 28%
+ High Efficiency Lighting 64% 0% 58% 36% 20% 31%
+ Open Slab Floors 64% 0% 79% 73% 27% 49%
Incremental Change
Cumulative Change

The second set of parametric results are for the use of direct evaporative cooling (package
2 measures). The fan flow for each measure is shown in Figure 20.

45

Figure 19: Fan Flow for Package 2 Measures

The hourly demand profile for package 2 measures on August 13 is shown in Figure 21.

46

Figure 20: Hourly Demand Profile for Package 2 Measures on August 13
The incremental and cumulative parametric results for Package 2 measures are shown in
Table 10.

47
Table 10: Parametric Results for Package 2 Measures
Lighting Plug Fans Cooling Total Average
Loads Peak
Demand
(kWh) (kWh) (kWh) (kWh) (kWh) (kW)
Baseline 1645 5372 395 1496 8907 4.5
+ Direct Evaporative Cooling 1645 5372 943 19 7979 3.6
+ High Performance Glazing 1645 5372 809 18 7844 3.3
+ Additional Wall Insulation 1645 5372 753 17 7786 3.2
+ Additional Ceiling Insulation 1645 5372 705 16 7738 3.1
+ External Shading 1645 5372 658 14 7690 3.0
+ High Efficiency Lighting 599 5372 630 13 6613 2.8
+ Open Slab Floors 599 5372 311 6 6288 1.8
+ Direct Evaporative Cooling 0% 0% -139% 99% 10% 21%
+ High Performance Glazing 0% 0% 14% 7% 2% 8%
+ Additional Wall Insulation 0% 0% 7% 5% 1% 3%
+ Additional Ceiling Insulation 0% 0% 6% 4% 1% 3%
+ External Shading 0% 0% 7% 11% 1% 3%
+ High Efficiency Lighting 64% 0% 4% 7% 14% 6%
+ Open Slab Floors 0% 0% 51% 52% 5% 36%
+ Direct Evaporative Cooling 0% 0% -139% 99% 10% 21%
+ High Performance Glazing 0% 0% -105% 99% 12% 27%
+ Additional Wall Insulation 0% 0% -91% 99% 13% 29%
+ Additional Ceiling Insulation 0% 0% -78% 99% 13% 31%
+ External Shading 0% 0% -67% 99% 14% 33%
+ High Efficiency Lighting 64% 0% -59% 99% 26% 37%
+ Open Slab Floors 64% 0% 21% 100% 29% 60%
Incremental Change
Cumulative Change

The comparative monthly electric consumption for baseline, package 1 and package 2
measures is shown in Figure 22

48

Figure 21: Monthly Electric Consumption for Baseline and Proposed Cases

The comparative monthly gas heating consumption for baseline, package 1 and package 2
measures is shown in Figure 23

Figure 22: Monthly Gas Heating Consumption for Baseline and Proposed Cases

49
Photovoltaics
A PV system was simulated to determine the relationship between orientation and peak
period power production. The azimuths were based on the sun angle at each hour from
12pm to 6pm on August 12. Tilt was set according to one of the following:

• Tilt = 25 degrees
• Tilt = sun angle
• Tilt = 90 degrees

The PV system consisted of 11 220V modules connected in series using a 2.5kW inverter.
The hourly peak profile for the PV system with a tilt of 25 degrees is shown in Figure 24.

50

Figure 23: Hourly Peak Profile for a 2.4kW PV System with Tilt = 25 Degrees
The hourly peak profile for the PV system with a tilt equal to the solar angle is shown in
Figure 25.

51

Figure 24: Hourly Peak Profile for a 2.4kW PV System with Tilt = Solar Angle
The hourly peak profile for the PV system with a tilt of 90 degrees is shown in Figure 17.

52

Figure 25: Hourly Peak Profile for a 2.4kW PV System with Tilt = 90 Degrees
The peak and annual production for each orientation is shown in Table 11.

53
Table 11: Summary of Peak Generation and Production from 2.4kW PV System
Time 12PM 1PM 2PM 3PM 4PM 5PM 6PM
Solar Azimuth (August 12) 180.0 218.5 241.2 255.3 265.4 273.8 282.1
2 - 3PM (kW) 1.67 1.79 1.80 1.78 1.76 1.73 1.70
3 - 4PM (kW) 1.44 1.65 1.71 1.72 1.71 1.69 1.66
4 - 5PM (kW) 1.05 1.39 1.50 1.53 1.53 1.52 1.50
Annual Production (kWh) 4,367 4,219 3,987 3,805 3,665 3,543 3,418
2 - 3PM (kW) 1.68 1.79 1.80 1.72 1.56 1.28 0.98
3 - 4PM (kW) 1.45 1.65 1.76 1.78 1.70 1.54 1.25
4 - 5PM (kW) 1.06 1.38 1.58 1.69 1.71 1.64 1.47
Annual Production (kWh) 4,297 4,210 3,956 3,573 3,116 2,627 2,140
2 - 3PM (kW) 0.68 1.02 1.05 1.00 0.93 0.85 0.76
3 - 4PM (kW) 0.48 1.09 1.23 1.24 1.22 1.17 1.11
4 - 5PM (kW) 0.24 1.05 1.32 1.42 1.43 1.40 1.34
Annual Production (kWh) 2,793 2,752 2,578 2,406 2,250 2,103 1,944
Tilt = Solar Angle
Tilt = 90 Degrees
Tilt = 25 Degrees

The relative power and energy production for each PV orientation relative to a basecase
of a tilt of 25 degrees and an azimuth of 162.7 degrees (12pm) is shown in Table 12.
Table 12: Relative Power and Energy Production by PV Orientation
Time 12PM 1PM 2PM 3PM 4PM 5PM 6PM
Solar Azimuth (August 12) 180.0 218.5 241.2 255.3 265.4 273.8 282.1
Tilt = 25 Degrees 0% 32% 43% 46% 46% 45% 43%
Tilt = Solar Angle 2% 32% 51% 61% 63% 56% 40%
Tilt = 90 Degrees -77% 1% 26% 36% 36% 34% 28%
Tilt = 25 Degrees 0% -3% -9% -13% -16% -19% -22%
Tilt = Solar Angle -2% -4% -9% -18% -29% -40% -51%
Tilt = 90 Degrees -36% -37% -41% -45% -48% -52% -55%
Annual Energy Production Relative to Azimuth = 180 and Tilt = 25 Degrees
Power Production Relative to Azimuth = 180 and Tilt = 25 Degrees at 4-5PM

Based on these results the orientations selected for further analysis were the 25 degree tilt
and solar angle, both at an azimuth of 255.3. The vertical PV orientation was not
included due to the low annual power production.
54

Zero Net Peak Demand
To achieve zero net peak demand the PV system was sized just large enough to achieve
zero demand during the peak period. A summary of the configuration and performance
characteristics required to achieve zero peak demand for the DX cooled homes is shown
in Table 13. To provide a comparison the table also includes a standard PV system,
azimuth of 180, tilt of 25 degrees, sized to meet annual energy consumption.
Table 13: Summary of PV System Required for DX Cooled Homes
PV Orientation Roofpitch* Roofpitch Solar Angle Roofpitch* Roofpitch Solar Angle
(South) (West) (West) (South) (West) (West)
Azimuth 180 255.3 255.3 180 255.3 255.3
Tilt 25 25 45.1 25 25 45.1
# Series Modules 8 10 9 8 8 7
# Strings 2 2 2 2 2 2
# of Modules (Total) 16 20 18 16 16 14
System Size (kW) 3.52 4.4 3.96 3.52 3.52 3.08
Inverter Size (kW) 3.3 4 3.8 3.3 3.3 3.3
Annual Energy Production (kWh) 6397 6991 5884 6397 5579 4534
Electricity Consumption (kWh) 6463 6463 6463 6288 6288 6288
Average Generation Peak (kW) 1.9 2.7 2.5 1.9 2.2 1.9
Average Demand Peak (kW) 2.5 2.5 2.5 2.0 2.0 2.0
TOU Rate ($) 39 39 39 39 39 39
Domestic Rate ($) 19 11 87 11 103 239
* PV sized to approximately meet annual energy consumption
SEER 15 Cooling + Measures Direct Evap Cooling + Measures

The resultant load profiles for each zero net peak home compared with the baseline are
shown in Figures 27 and 28.

55

Figure 26: Zero Net Peak Load Profiles Compared with Baseline

56

Figure 27: Zero Net Peak Demand Compared with Baseline on August 12
To verify if zero net peak demand would be achieved earlier in the summer period the
load profile is shown for June 1 in Figure 29.
57

Figure 28: Zero Net Peak Demand Compared with Baseline on June 1
Life Cycle Costs
A lifecycle cost analysis was performed to compare the relative costs of the two solar
orientations versus the standard PV orientation of 25 degree tilt and 180 degree azimuth.
The results are shown in Table 14.

58
Table 14: Net Present Value Analysis of Alternatives
PV Orientation Roofpitch Roofpitch Solar Angle Roofpitch Roofpitch Solar Angle
(South) (West) (West) (South) (West) (West)
Azimuth 180.0 255.3 255.3 180.0 255.3 255.3
Tilt 25.0 25.0 45.1 25.0 25.0 45.1
First Cost $39,537 $46,577 $43,057 $38,539 $38,539 $35,019
PV Rebate @ $2.60/watt -$9,152 -$11,440 -$10,296 -$9,152 -$9,152 -$8,008
Federal PV Tax Credit -$2,000 -$2,000 -$2,000 -$2,000 -$2,000 -$2,000
Federal Energy Efficiency Tax Credit -$2,000 -$2,000 -$2,000 -$2,000 -$2,000 -$2,000
Tier 2 Utility Rebate -$2,000 -$2,000 -$2,000 -$2,000 -$2,000 -$2,000
First Cost After Rebates $24,385 $29,137 $26,761 $23,387 $23,387 $21,011
NPV Before Rebates -$25,394 -$32,736 -$29,565 -$24,739 -$24,413 -$20,893
NPV After Rebates -$10,241.92 -$15,295.63 -$13,268.78 -$9,587.39 -$9,260.61 -$6,884.61
SEER 15 Cooling + Measures Direct Evap Cooling + Measures

The installed cost of the PV per watt required to achieve a net present value of zero in
shown in Table 15.
Table 15: Installed Price of PV Necessary to Achieve NPV=0
PV Price
($/Watt)
SEER 15 Cooling + Measures
Roofpitch $4.52
Solar Angle $4.65
Direct Evap Cooling + Measures
Roofpitch $5.37
Solar Angle $5.76

Using the time dependant valuation load profile as a basis, a theoretical TOU electrical
rate was developed. The range of TOU rates required to achieve an NPV of 0 for each
scenario was calculated for PV costs of $8 and $5 per watt. The TOU price profile for
August 13 is shown in Figure 30.

59
$0.00
$0.20
$0.40
$0.60
$0.80
$1.00
$1.20
$1.40
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Hour
Hourly Electric Tariff Rate ($/kWh)
PV @ $8/Watt
PV @ $5/Watt

Figure 29: Proposed Tariff Rates on August 13 Required to Achieve NPV = 0
60
Chapter Six: Evaluating Zero Peak Demand Performance
This chapter discusses the results presented in Chapter 4 and examines the impact of
weather, energy efficiency measures and PV systems on peak demand. The primary
focus is on the requirements for achieving zero peak demand, the lifecycle costs and the
relevance of the results to residential developments in California.
Weather Conditions
The weather conditions during the peak period represent extreme summer conditions
characterized by high temperatures and low humidity. The dry bulb temperature peaks at
between 93 and 103 degrees while the humidity is between 13 and 27%. Figure 31 taken
from the Consumer Energy Center shows the temperatures that can be achieved by a
direct evaporative cooling system relative to air temperature and relative humidity.

Figure 30: Optimum Conditions for Direct Evaporative Cooling

61
Given that the hottest temperatures during the peak period occur when relative humidity
is below 20%, a direct evaporative cooling system can be expected to maintain indoor
temperatures of approximately 74 to 81 degrees. The higher airflow rates and reduced
infiltration due to the positive pressurization of the space will further improve comfort.
Based on the weather conditions during the peak period direct evaporative cooling
appears to be a viable cooling strategy. The assumption has been made that evaporative
cooling would also be appropriate during the remainder of the cooling season although
this may potentially not be the case if periods of high humidity occur simultaneously with
high temperatures.

The availability of the solar resource during the peak period is reduced due to the
presence of cloud cover. On August 14 the level of cloud cover, on a scale of 1-10
ranges from 7 to 8. Figure 32 shows how the level of direct normal radiation is impacted
by cloud cover.

62

Figure 31: Direct Normal Radiation versus Cloud Cover During Peak Period
At 5pm on August 12 and 13 direct normal radiation is between 210 and 211 Btu/hr-ft2
while at 5pm on August 14 radiation drops to 12 Btu/hr-ft2. Capturing the same amount
of solar resource on August 14 would require an area 13 times larger than that required
on August 12 and 13. This result clearly indicates that a PV system is not going to be
effective in addressing peak demand on August 14.

The simulated weather data is only representative and actual conditions in any given year
may be significantly different. The weather data used in this simulation for climate zone
10 is in Typical Meteorological Year 2 (TMY2) format and is based on a data gathered
between 1961 and 1990 which has been statistically averaged. A comparison of hourly
temperatures between two Southern California Edison weather stations (12.1 and 12.2)
63
and the TMY2 data reveals that actual temperatures between 2001 and 2006 were on
occasion much higher. While the TMY2 indicated a peak temperature of 104, peak
temperatures of between 104 and 112 were recorded between 2002 and 2006. It is
reasonable to expect that weather data will vary between different weather stations even
those in the same region due to microclimate issues, natural variability in the weather and
the accuracy of the instrumentation. Even so these results indicate that the simulated
performance of residential buildings based on TMY2 data may differ significantly from
the actual performance on these buildings when placed in the field. More specifically the
zero peak residential building design developed in this thesis based on simulation may
not always perform as a zero peak residential building in the field.
Baseline Energy Performance
Building orientation was found to impact annual energy use, peak demand, cooling
capacity and the annual utility bill. The annual electric consumption is 8,907 kWh at the
E-W (long axis) orientation and increases by 4% when at the N-S orientation (due to
increased exposure to east and west sun angles). The peak demand is 4.52 kW at the E-
W and increased by 11% when at the N-S orientation. The cooling capacity required to
achieve zero unmet cooling load hours rises from 43,000 at the E-W orientation to 49,000
at the N-S orientation, an increase of 14%. Likewise the electric bill rises from $1,593 at
the E-W orientation to $1,688 at the N-S orientation, an increase of 6%. Clearly the
choice of orientation can significantly impact energy use and peak demand in a code
compliant building and minimizing east and west solar exposures is beneficial.

64
Although space cooling is a significant contributor to overall annual energy use it has a
far larger influence on peak demand. Only 21% of the annual energy use is due to
compressor cooling and ventilation and part of this includes fan energy during the heating
season. At 5PM on August 13 compressor cooling and ventilation account for 82% of the
electrical load. To be successful in reducing peak demand the cooling load must be
reduced and the efficiency of the cooling equipment must be as high as possible.

Non air conditioning related end-uses contribute most to demand after 5PM. Lighting
and plug loads peak between 6 and 9PM and so can’t be met using PV. A zero peak
home based on the definition used in this thesis will still have a peak demand sometime
during the evening hours. This evening peak is far less than the air conditioning peak
during the afternoon and so poses far less of a challenge to electric generation and
distribution infrastructure.

The thermal characteristics of the house allow for significant penetration of sensible heat
due to the solar load during the peak period. The primary mechanism for solar load is
through the window glass and frame. The secondary mechanism is through infiltration.
Internally generated loads from lights, occupants and equipment contribute relatively
little to the load. Radiation and conduction of heat through the windows contributes 47%
of the heat gain to the 1
st
story and 53% to the second story. Wall conduction is the next
largest contributor followed by infiltration. These results are typical for residential
buildings which have loads which are typically dominated by the solar load on the
envelope.
65
Parametric Analysis
Both packages of energy efficiency measures provided a dramatic reduction in peak
demand. Package 1 which included SEER 15 cooling provided a 49% reduction in peak
demand and Package 2 which included direct evaporative cooling provided a 60%
reduction in peak demand. Overall energy use was also reduced by between 27% and
29%. Furthermore, for both packages, the size of the cooling system could be reduced
which reduces the first cost of the cooling system. The implementation of these types of
energy efficiency packages significantly reduces the size of the PV system required to
zero out the remaining load.

The size of the cooling system required to achieve zero unmet cooling load hours in the
1
st
and 2
nd
stories of the home was far less after the integration of the energy efficiency
measures. The baseline DX cooling system was 43,000 Btu/hr but could be reduced by
49% to 22,000 Btu/hr in Package 1. The use of direct evaporative cooling required 7,500
cfm in the baseline but could be reduced by 53% to 3,500 cfm in Package 2. Not only
does this reduce the cost of the cooling unit but the size of the ducts can also be reduced
due to the lower volume airflow.

The use of a high efficiency cooling system caused a significant drop in peak demand in
annual energy use. The SEER 15 DX system and direct evaporative system reduced peak
demand by 14% and 21% respectively. The SEER 15 DX system reduced electrical
energy use by 3%, most of which came from reduced fan energy. The direct evaporative
system reduced electrical energy use by 10% by almost eliminating compressor and
66
pumping energy but increasing fan energy. These results include an assumption that both
cooling systems provide comparable comfort. It is possible that the humidity added to
the space may render the direct evaporative system inappropriate during periods of high
temperatures and high humidity. It is also possible that the efficiency of the SEER 15
DX system, which is based on a test standard outdoor temperature of 82 degrees F, is
considerably reduced during the peak period.

The envelope related measures in Package 1 and 2 all reduced peak demand and annual
energy use. The combined impact of high performance glazing, additional wall and
ceiling insulation and external shading on peak demand was an 18% reduction for
Package 1 and a 17% reduction for Package 2. The resulting load profile was identical in
shape to that of the cooling system but reduced in magnitude.

Not surprisingly, high efficiency lighting resulted in a much larger percentage reduction
in electrical energy use than peak demand due to the concentration of lighting demand in
the evening. Some benefit was still gained however with peak demand reductions of 3%
for Package 1 and 6% for Package 2. High efficiency lighting also flattened the load
profile, creating an almost constant peak demand from early afternoon to early evening.

The open slab floor provided a very large reduction in peak demand due to the thermal
storage effect during the peak period. Peak demand was reduced by 26% for Package 1
and 36% for Package 2. Given the limitations in eQuest in simulating thermal mass it is
possible that the benefit of thermal mass may be properly captured in the simulation.
67
Heat transfer to and from the slab floor is highly dependant on air flow patterns which are
not taken into account in eQuest. The impact of the slab floor on mean radiant
temperature is also being ignored. There is also uncertainty as to whether the slab floors
are able to fully discharge their heat during the night so the thermal storage effect can be
duplicated on the second or third peak day. Assuming eQuest’s results are accurate,
thermal mass provided the largest reduction in peak demand of any of the measures.

PV System Orientation
Configuring PV orientation to maximize annual energy production results in a different
orientation than when oriented to minimize peak demand. To understand when and how
orientation impacts energy and power production three different tilts at varying azimuths
were evaluated. The three tilts consisted of roof pitch (25 degrees), solar angle (90
degrees minus sun angle) and vertical (90 degrees). Each of these approaches were
compared to a typical PV installation with an azimuth of 180 degrees and tilt of 25
degrees in terms of peak period power production and annual energy production. Not
included in this analysis is the thermal impact on the building envelope of shading from
the PV modules.

PV installed at a roofpitch tilt with a westerly orientation can significantly increase power
production during peak periods. For the time period of 4 -5 pm on August 12, an azimuth
of 180 degrees, tilt of 25 degrees provides 1.05 kW while an azimuth of 255.3, tilt of 25
degrees provides 1.53 kW, an increase of 46%. Selecting a more westerly orientation
68
reduces annual energy production. While an orientation of azimuth of 180 degrees, tilt of
25 degrees produces 4,367 kWh annually, this falls by 13% to 3,805 kWh for an azimuth
of 255.3, tilt of 25 degrees.

PV installed at a solar angle tilt provides the largest increase in peak production of all the
orientations evaluated. Setting the tilt according to the solar angle ensures that at some
point during the peak period the PV module is normal to the sun’s rays. This represents
the best possible outcome for fixed PV although installing at tilt angles different from the
roofpitch may not necessarily be practical. For the time period of 4 -5 pm on August 12,
an azimuth of 180 degrees, tilt of 25 degrees provides 1.05 kW whiles an azimuth of
255.3, tilt of 90 degrees minus sun angle provides 1.69 kW, an increase of 60%. While
an azimuth of 180 degrees, tilt of 25 degrees produces 4,367 kWh annually, this falls by
18% to 3,573 kWh for an azimuth of 255.3 degrees, tilt of 90 degrees minus sun angle.
This actually suggests a change in building form if building integrated photovoltaics are
contemplated.

PV installed at vertical tilt provides a significant increase in peak production but with a
large reduction in annual energy production. For the time period of 4 -5 pm on August
12, an azimuth of 180 degrees, tilt of 25 degrees provides 1.05 kW while an azimuth of
255.3, tilt of 90 degrees provides 1.42 kW, an increase of 36%. While an azimuth of 180
degrees, and a tilt of 25 degrees produces 4,367 kWh annually, this decreases by 45% to
2,406 kWh for an azimuth of 255.3 degrees and tilt of 90 degrees. The low annual
energy production combined with the practical limitations of avoiding shading on a
69
vertical PV installation indicate that this configuration is less desirable than roof pitch
and solar angle configurations. Based on these results the vertical PV was not considered
for further analysis.

The roof pitch and solar angle PV both appear to provide significant potential for
increased peak production (46 – 60%) with only a small reduction in annual energy
production (13 – 18%). The increased peak afternoon production is very helpful in
reducing demand in the late afternoon when the peak occurs and is preferable to
oversizing the PV to achieve a similar result.

Zero Net Peak Demand
The right combination of high efficiency measures and a PV system can produce a zero
peak demand profile. A zero peak demand profile was achieved using between 3.1 and
4.4 kW of PV while by comparison zero annual electrical consumption can be achieved
using 3.3 kW of PV. In all cases the TOU rate allowed the cost of electrical energy to be
eliminated through net metering, leaving only the fixed portion of the utility bill ($39 /
year). A zero peak profile was achieved for August 12th and 13
th
but could not be
achieved on August 14
th
due to cloud cover. Since the PV system was sized to meet
average peak demand using the 9-hour average the low production on August 14
th
was
accounted for in this analysis.

70
In the case of package 1 energy efficiency measures, zero peak demand is achieved using
4.4kW for PV oriented at roofpitch and 4.0kW for PV oriented at solar angle. Compared
with roofpitch PV the solar angle PV required 2 less PV modules which at $8/installed
watt saves $3,520 in first costs. Although the roofpitch PV produces more annual
energy that consumed at 6,991 kWh, the solar angle PV, due to its smaller size produces
less at 5,884 kWh.

In the case of package 2 energy efficiency measures, zero peak demand is achieved using
3.5kW for PV oriented at roofpitch and 3.1kW for PV oriented at solar angle. Compared
with roofpitch PV the solar angle PV required 2 less PV modules which at $8/installed
watt saves $3,520 in first costs. In terms of annual energy both the roofpitch and solar
angle PV produce less annual energy than consumed with the roofpitch PV producing
5,579 kWh and the solar angle PV producing 4,534 kWh.

Matching peak generation and annual energy production with the actual demand and
consumption of the house is limited by the capacity and configuration of the PV modules.
In cases where the PV was sized to meet peak demand the variation between peak
generation and peak demand was 10% or less. In cases where the PV was sized to meet
annual energy consumption the variation between consumption and generation was 2% or
less. Incorporating the limitations of PV system design into this analysis means that the
results are representative of what can be achieved in the field.

71
The number of panels can easily be accommodated by the available roof area. One side
of the pitched roof represents 944 sqft, theoretically enough space for 70 panels each of
which is 13.4 sqft. The maximum number of panels required to achieve zero peak is only
20 panels.

While the solar angle PV provides better peak performance than roof pitch PV it does not
necessarily provide better annual energy performance. While the lower annual
production of the solar angle PV is in part due to the smaller size, it is also due to the
high tilt which reduces access to solar energy during the middle of the day when the sun
is higher in the sky.

The 4 – 5pm peak production capacity factor was very consistent for both roofpitch and
solar angle PV. Peak production capacity factor is defined here as Average kW Peak per
kW of installed capacity. The capacity factor was 0.62 for both the roofpitch and solar
angle PV (0.62 kW of average peak production / kW installed capacity) but only 0.52 for
the reference PV (azimuth 180 and tilt of 25). This provides a helpful rule of thumb for
sizing PV systems based on this particular simulation model. Based on this definition of
capacity factor, meeting a 5kW average 4 -5 pm peak would require an 8.1 kW PV
system.

While the roofpitch PV orientation can typically be accommodated on a standard
residential roof, the solar angel PV requires a tilt angle that is much higher than the slope
of most residential roofs. Mounting solar angle PV would either require a redesigned
72
roof geometry or, more likely, a pole mounted configuration which may be both more
expensive and less aesthetically desirable.

One aspect of the PV systems not taken into account in this analysis is the interaction
between the PV and the house. Mounting a PV system on the roof will cause some level
of shading and may even increase attic temperature in the case of dark colored building
integrated PV systems. Additionally achieving the best PV azimuth, which in this case
was 255.3 degrees, is quite different from the south facing orientation required for the
house to minimize solar gain. These two issues, if incorporated into the simulation model,
may produce different results.

The results indicate that the zero peak profile occurs not only during the peak demand
days of August 12 – 14 but also earlier in the summer on June 1. Even though the sun
position varies, the zero peak profile appears to be fairly robust assuming over most of
the summer period assuming clear skies.
Lifecycle Cost Assessment
The lifecycle cost assessment indicates that neither the zero peak or zero energy PV
configuration achieved a positive net present value (NPV). The roofpitch and solar angle
PV achieved an NPV of between -$6,884 and -$15, 295. The reference south facing PV
achieved an NPV of -$10, 241. The larger PV system required to achieve zero peak for
package 1 meant that the NPV was worse than the reference south facing PV. The
smaller PV system required to achieve zero peak for package 2 meant that the NPV was
73
better than the reference south facing PV. This implies that the aggressive reductions in
peak cooling demand made possible by the use of the direct evaporative system enabled
the PV system to be downsized to the point that the NPV of achieving a zero peak house
was larger than for a zero energy house. The stated NPV is highly dependant on rebates
and tax credits which reduced first costs by $14,000 to $17,000.

One cost assumption which has a large impact on the NPV is the installed cost of the PV.
The cost assumption used here was $8/watt but lower costs which may occur in the future
will significantly improve the NPV. A drop in the installed cost to the range of $4.52 to
$5.76 would result in a zero NPV. This would mean a homeowner, financing the
incremental costs using a home mortgage could potentially experience zero cash flow
over the life of the PV system. Theoretically this means they would be indifferent
between doing nothing or paying the costs associated with a zero peak house.

While this lifecycle cost assessment used current tariff structures, these could change in
the future, which would also change the NPV result. Time-of-use meters will be rolled
out into the residential market in Southern California Edison’s territory beginning in 2009.
These meters will support the implementation of time-of-use tariffs which include
varying hourly charge rates which better reflect the real cost of generation. The time
dependant valuation (TDV) method used in Title 24 approximates one possible cost
profile which could be used in a time-of-use tariff. Using the TDV profile it was possible
to define a cost profile for each PV orientation and measure package which achieved a
zero NPV. For PV with an installed cost of $8/watt this would require a TOU tariff with
74
a peak rate on August 13
th
of $1.03 to $1.28 per kWh. For PV with an installed cost of
$5/watt this would require a TOU tariff with a peak rate on August 13
th
of $0.62 to $0.76
per kWh.

75
Chapter Seven: Implications for Building Design
The use of intelligent passive building design, appropriate energy efficiency measures
and PV systems can fundamentally reshape the electric load profile of residential
buildings. Rather than contributing to grid congestion zero peak buildings can eliminate
the electric demand footprint which threatens to destabilize California’s electric grid each
summer. Should the building industry and consumers embrace a shift to such buildings,
many millions of dollars in additional generation facilities, transmission lines and
distribution circuits could potentially be avoided along with the negative environmental
impacts. Zero peak is only one such attribute of an ideal sustainable building future.
Zero energy, zero carbon, even zero water footprint buildings are also very important
goals. What is particularly unique about zero peak is that failure to address grid
congestion brings swift and disastrous consequences such as rolling blackouts which not
only bring business and daily life to a halt but also threaten lives. This thesis
conclusively demonstrates, within the limitations of building energy simulation, that zero
peak residential buildings are technical possible and could potentially be made cost
effective.

Peak demand is almost entirely driven by afternoon solar gain and the subsequent cooling
load. While air conditioning only accounts for 21% of annual electrical energy it
represented 81% of the peak electrical load at 5pm during the peak period. Obviously
those strategies which address the need for mechanical air conditioning will have the
most significant impact on peak demand. Unlike most non-residential buildings in which
76
the cooling load is drive by internal gains, the cooling load in residential buildings is
almost entirely weather dependant.

The peak demand profile can be reshaped through the use of appropriate energy
efficiency measures which address the cooling load. By increasing window performance,
building tightness, insulation, thermal mass, shading and cooling unit efficiency
combined with unit downsizing, the peak demand profile can be significantly flattened.
The combination of these strategies reduced the peak demand by 49 – 60% while also
allowing a downsizing of the cooling unit size of 49 – 53%.

The orientation of the PV system is a major factor in determining the production of
electricity during the peak period. The use of a westerly orientation with an azimuth of
255 degrees and a tilt of 25 to 45 degrees increases peak production compared with south
facing PV at a tilt of 25 degrees by 46 to 60%. While this assumes appropriate roof
geometry is clearly demonstrates the potential value of PV during peak.

A zero peak residential demand profile can be achieved through the integration of energy
efficiency measures and a moderately sized PV system. The PV system required to
achieve zero electrical demand at 5pm during a peak day ranged from 3.1 to 4.4 kW. Not
only did the PV systems eliminate peak but they also reduced the electric utility bills
almost to zero. The amount of PV required can, given the right roof geometry, be easily
accommodated on a residential roof.

77
Zero peak performance is highly sensitive to weather conditions. Although in climate
zone 10 high peak demand is likely to coincide with clear skies this may not always be
the case. The peak demand period for climate zone 10 clearly indicates that high cloud
cover during the hot afternoon period does occur and these conditions will significantly
undermine PV performance.

Current costs structures mean that zero peak residential buildings are not cost effective
but are similar in terms of NPV to a zero energy residential building. The NPV for zero
peak ranged from - $6,884 to -$15, 295 while zero energy had a NPV of -$10,241.
Despite a large reduction in long term energy costs the upfront costs of the energy
efficiency measures and PV system remain high even when factoring in rebates and tax
credits.

Changes in the cost environment, driven by higher energy prices or technological
innovative could allow the cost effectiveness of zero peak residential buildings to achieve
a zero NPV. A drop in the installed cost of PV systems from the current $8/watt to $4.52
would boost the NPV to zero. Similarly a move to an hourly time-of-use electricity tariff
with a peak charge of $0.76/kWh would also achieve zero NPV. There is already a
considerable amount of momentum in the marketplace which may bring about favorable
cost changes in both of these areas.

Zero peak residential buildings deserve serious attention by electric utilities and
government agencies as a way of addressing peak demand. While there are many
78
programs in place to encourage reduction in the use of certain electrical appliances and
loads during peak periods, there is no such attention placed on the goal of zero peak in
either residential or non-residential buildings. Dispatchable demand response programs
which allow utilities to drop customer load when serious peak period conditions arise
have been shown to be very effective but this approach requires constant vigilance by the
utility and is limited in its potential. An inherently better approach is to permanently
reshape the demand profile of buildings by encouraging zero peak design. Until cost
effective and practical forms of energy storage become widely available, the most
effective way to harness the solar resource is to match building demand with rates of
insolation. Zero peak residential buildings represent a way to achieve this result and
efforts to encourage this type of design and system integration should be encouraged in
California.

79
Chapter Eight: Areas for Future Research
This thesis focused on the specific goal of evaluating how a zero peak demand residential
building could be achieved using a fairly conventional set of technologies and
photovoltaic systems. Having demonstrated the a zero peak load profile can be achieved
the is a considerable amount of future work that is required to fully explore and evaluate
not only zero peak residential buildings but also many of the designs and technologies
that can contribute to this kind of building. As the imperative for zero energy, zero peak
and zero carbon buildings increases, it will become even more critical to increase our
understanding of how to design these kinds of buildings to minimize energy consumption,
harness opportunities for on-site renewable energy production and provide an economic
value proposition for the builder and home buyer.

One area in which much additional work is needed is the development and application of
simulation tools which can model passive cooling systems. Clearly mechanical cooling
systems are the largest driver of peak demand so eliminating or significantly reducing the
needs for these systems is important in zero peak buildings. New simulation tools are
needed which need to be able to handle not only natural ventilation systems but also
thermal mass and its impact on mean radiant temperature.

One approach to increasing the production capacity of PV systems is the use of solar
tracking systems. Mechanical single or dual axis trackers adjust orientation to maximize
energy production. These systems are not subject to the same tradeoffs between annual
energy production and peak generation as fixed orientation systems. The use of tracking
80
systems to achieve zero peak needs to further studied. This research should also take into
account the cost impacts of these systems as well as the maintenance requirements and
impact on building aesthetics.

There are many more energy efficiency measures which could be integrated into a zero
peak house beyond what was considered in this thesis. Advanced direct expansion or
evaporative cooling systems can provide higher levels of energy efficiency than the
systems included in this analysis. There are also other types of envelope systems that
could be explored such as structurally insulated panels, insulated concrete forms and
compressed earth. Rather than using fixed exterior shading, dynamic louvers or blinds
which respond to temperature and sun angle could also be considered.

While this thesis focused on one house the electrical grid is exposed to millions of such
houses so load diversity must be taken into account. Plug loads which can vary
significantly from house to house, due to occupant preferences, are an example of a high
level of diversity. Even air conditioning loads will vary between houses depending on
the level of solar gain and internal loads. Understanding the diversified load profile
requires an analysis of populations of houses.

New kinds of smart electrical meters which will shortly rollout to the residential market
in California will open up many new opportunities to impact demand. These meters will
allow the use of more sophisticated time of use tariffs, real time displays of energy
consumption and remote control of building appliances by homeowners and utilities. It
81
would be very valuable to research the ways in which homeowner behavior changes as a
result of this new technology and how this impacts peak electrical demand.

The impact of variable weather patterns on the peak consumption and PV system
production needs further study. Weather patterns are obviously much more variable than
can be represented in a single TMY2 weather file. As revealed in this thesis, high cloud
conditions can be present during high temperature periods and this impacts PV system
production. It would be valuable to simulate results using a set of 10 to 20 years of
weather data and to develop statistical probabilities for achieving a zero peak load profile.
An evaluation of the weather impacts due to global warming would also be an interesting
element of this analysis.

There is a need to improve our understanding of the tradeoffs between the building
orientation required to minimize peak energy consumption and the PV orientation
required to maximize peak energy production. Typical roof geometries are not designed
with these issues in mind and can create a problem when trying to achieve zero peak.
This thesis ignored these impacts to simplify the analysis but in practice new building
envelope designs and roof geometries will be required. More research is needed to
explore ways of reducing the tradeoffs between energy consumption and generation.

Zero peak residential buildings require a great deal more research and analysis in order to
achieve the best performance. Much can be done to improve residential building designs
and technologies to achieve zero peak performance beyond what has been demonstrated
82
in this thesis. Developers, builders and homeowners will also need more information on
the cost, aesthetics and maintenance of a zero peak residential building. This research is
represents an exciting new area which is increasingly critical in California and throughout
the world as energy issues and global warming take on increasing prominence and
urgency.
83
Glossary

British Thermal Unit: A unit of energy equivalent to that required to raise one pound of
water by one degree Fahrenheit.

California Climate zone: Geographically specific region of California which is
represented by a weather data file containing 8,760 hours of weather data thought to be
typical of a typical weather year.

Kilowatt Hour: The amount of energy consumed by one kilowatt of power.

Kilowatt: A unit of electrical power equivalent to 1000 watts.

Megawatt Hour: A measurement of energy equivalent to 1000 Kilowatt hours.

Peak Demand: The average grid level impact for an energy efficiency measure from 2
p.m. to 5 p.m. during the three consecutive weekday period containing the weekday with
the hottest temperature of the year

Photovoltaic: Solar power technology which uses solar cells to convert light from the
sun directly into electricity.

84
SEER: Seasonal Energy Efficiency Ratio which is used to rate the cooling performance
of air conditioners. SEER is defined as the Btu of cooling output during a typical cooling
season divided by the total electric input in watt hours during the same period.

Therm: One hundred thousand British Thermal Units.

Watt: Unit of power equivalent to one joule of energy per second.

85
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005.PDF [Accessed 28 November, 2006]

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Available from: http://www.fypower.org/pdf/Calif_DemandResp_FYP_Final.pdf
[Accessed 28 November, 2006]

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[online]. Available from:
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California Energy Commission 2006d, California Energy Demand 2006-2016 Staff
Energy Demand Forecast,September 2005, Staff Final Report, CEC-400-2005-034-SF-
ED2. p106, Available from:
http://www.scag.ca.gov/rcp/pdf/publications/2_2006_2016EnergyDemand_CECrev.pdf
[Accessed on January 23, 2007]

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Outlook, Final Staff Report, April 2006, CEC-700-2006-005

California Energy Commission, 2006f, Staff Forecast of 2007 Peak Demand, Staff
Report, June 2006, CEC-400-2006-008-SF

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CMF.PDF [Accessed on January 23, 2007]

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on SMUD’s Peak Load, 2006 ACEEE Summer Study on Energy Efficiency in Buildings

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Controlling Peak Electricity Demand, Lawrence Berkeley National Laboratory, LBNL-
49947

Pacific Gas and Electric, 2003, Time Dependant Valuation (TDV) – Economics
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September 21, 2005.

Xu, P., Haves, P., Braun, J. and Hope, L. 2004, Peak Demand Reduction from Pre-
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Xu, P., Haves, P., and Piette, M., 2005, Demand Shifting With Thermal Mass in Large
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89
Appendix A: DEER Building Assumptions
UNITS Garage Ground Floor Top Floor
BUILDING SHELL
GENERAL
Outside ground reflectance 0.2
Outside emissivity 0.9
Inside solar absorbtance 0.5
Area sqft 426.4 1392 1392
Space type Unconditioned Conditioned Conditioned
Infiltration cfm/ft2 0.2125 0.0496 0.0496
Fraction of floor covered by furniture 0.2 0.2 0.2
Furniture weight
Floor to ceiling height 8.5 8.5 8.5
DOORS
Number of doors 2 2 0
Construction type Uninsulated metal Wood Wood
U-value Btu/hr-sqft-F 2.08 0.69 0.69
Exterior color absorbtance 0.7 0.7 0.7
EXTERIOR WALLS
Construction type 1" of stucco, building paper,
framing, 0.5" gypsum board
1" of stucco, building paper,
insulation, framing, 0.5"
gypsum board
1" of stucco, building paper,
insulation, framing, 0.5"
gypsum board
U-value Btu/hr-sqft-F 0.422 0.055 0.055
Exterior color absorbtance 0.6 0.6 0.6
ROOF
Construction type 3/8" clay tile paver, 3/8"
built up, building paper,
5/8" plywood, framing,
insulation, 5/8" gypsum
board
3/8" clay tile paver, 3/8"
built up, building paper,
5/8" plywood, framing
3/8" clay tile paver, 3/8"
built up, building paper,
5/8" plywood, framing
U-value Btu/hr-sqft-F 0.027 0.46 0.46
Exterior color absorbtance 0.58 0.58 0.58
ATTIC FLOOR
Construction type Framing, insulation, 5/8"
gypsum board
U-value Btu/hr-sqft-F 0.027
Floor
Construction type Ground, 12" damp soil, 4"
concrete, carpet
Ground, 12" damp soil, 4"
concrete, carpet
Framing, 1" plywood,
carpet
U-value Btu/hr-sqft-F 0.215 0.085 0.313
WINDOWS
Window frame conductance Btu/hr-sqft-F 4.09 4.09
Window frame absorbtance 0.7 0.7
Spacer type Aluminum Aluminum
Shading coefficient 0.46 0.46
Glass conductance Btu/hr-sqft-F 0.64 0.64
Visible transmittance 0.81 0.81
Outside emissivity 0.84 0.84
Shading type Fixed interior Fixed interior
Impact Solar gain reduced by 38% Solar gain reduced by 38%
Two Storey
90
UNITS Garage Ground Floor Top Floor
INTERNAL LOADS
Occupancy People 0.02 4 4
Lighting Watts 95 573 1212
Misc. Equipment Watts 0 680 450
HVAC
System type
Cooling Setpoint deg F
Heating Setpoint deg F
Cooling design temperature deg F
Heating design temperature deg F
Cooling capacity Btu/h
Heating capacity Btu/h
Cooling unit efficiency SEER
Heating unit efficiency AFUE
Duct air loss %
Supply duct outside air %
Thermal conductivity of supply duct Btu/h-F
Thermal conductivity of return duct Btu/h-F
Supply fan efficiency kW/cfm
Temp rise across supply fan deg F
Supply flow design cfm
Economizer
NATURAL VENTILATION
Air changes per hour
Operational schedule
Design temperature deg F
Probability that windows are open
24/7 from 5/1 to 9/30
72
0.5
Two Storey
1.15
1357
None
3
10
99.72
56.82
0.000364
67580
10
0.78
7
68
75
72
43335
Split system single zone DX with furnace
78

Sleeping
Area
Sleeping
Area
Living
Area
Living
Area
WD WEH WD WEH WD WEH WD WEH WD WEH
Midnt-1 1 1 0 0 0.465 0.4703 0.4668 0.4661 0.425 0.4728
1-2am 1 1 0 0 0.315 0.3143 0.2946 0.2944 0.295 0.3266
2-3am 1 1 0 0 0.2775 0.2772 0.2768 0.2767 0.2625 0.2918
3-4am 1 1 0 0 0.24 0.24 0.253 0.253 0.23 0.257
4-5am 1 1 0 0 0.2475 0.24 0.2649 0.2648 0.23 0.257
5-6am 1 1 0 0 0.24 0.24 0.2946 0.2944 0.23 0.257
6-7am 0.5 1 0.5 0.5 0.36 0.3589 0.3718 0.3714 0.3275 0.3684
7-8am 0.33 0.5 0.33 0.67 0.4725 0.4703 0.4371 0.4365 0.425 0.4658
8-9am 0 0 0.33 0.67 0.5025 0.5001 0.4847 0.4839 0.4575 0.5006
9-10am 0 0 0.33 0.67 0.5325 0.5298 0.5381 0.5372 0.49 0.5284
10-11am 0 0 0.33 0.67 0.6 0.5892 0.5381 0.5431 0.542 0.5841
11-12pm 0 0 0.33 0.67 0.6525 0.6487 0.5559 0.5608 0.594 0.6398
12-1pm 0 0 0.33 0.67 0.6225 0.6189 0.5381 0.5372 0.5745 0.612
1-2pm 0 0 0.33 0.67 0.6 0.5966 0.5203 0.5194 0.555 0.598
2-3pm 0 0 0.33 0.67 0.5925 0.5892 0.5203 0.5253 0.542 0.5841
3-4pm 0 0 0.33 0.67 0.5825 0.5818 0.5262 0.5253 0.542 0.5772
4-5pm 0 0 0.33 0.67 0.735 0.7304 0.6213 0.62 0.672 0.7233
5-6pm 0 0 0.33 1 0.8925 0.879 0.7163 0.7148 0.802 0.8625
6-7pm 0 0 1 1 0.93 0.9236 0.7104 0.7088 0.8345 0.9043
7-8pm 0 0 1 1 0.99 0.983 0.7163 0.7207 0.88 0.953
8-9pm 0 0 1 1 0.9225 0.9161 0.7876 0.7917 0.8215 0.8904
9-10pm 0 0 1 1 0.8425 0.8344 0.847 0.845 0.7435 0.8138
10-11pm 0.5 0.5 0.5 0.5 0.7425 0.7378 0.7401 0.7444 0.659 0.7233
11-Midnt 1 1 0 0 0.63 0.6189 0.645 0.6437 0.555 0.612
WD = Weekdays
WEH = Weekends and Holidays
1/1-2/28, 12/1-12/31 4/1-9/30 3/1-3/31, 10/1-11/30
Occupancy Plug Loads

91
Appendix B: Calculation of Lighting Power

2-STORY HOUSE
Space Description
Average
Operating
Hours
(Manual
Switch)
2
Room Type
Distribution
3
Average # of
Fixtures per
room
Average # of
lamps per
room
1
Average
Lamp
Wattage
4
Total Room
Wattage
Average
Lamp
Wattage Total Wattage
TOP FLOOR
Bedroom 1.60 4.00 0.90 1.48 58 342 23 136
Bathroom 1.50 3.00 1.40 5.00 58 870 14 210
TOTAL 1212 346
GROUND FLOOR
Family Room 2.50 1.00 1.00 1.64 58 95 23 38
Halls/entry 1.60 1.00 0.80 1.31 58 76 15 20
Kitchen/Dining 3.50 1.00 3.10 5.08 23 117 23 117
Living Room 3.30 1.00 1.00 1.64 58 95 23 38
Laundry/Utility Room 1.20 1.00 1.00 1.64 58 95 23 38
Study 1.90 1.00 1.00 1.64 58 95 23 38
TOTAL 573 287
GARAGE
Garage 2.50 1.00 1.00 1.64 58 95 32 52
TOTAL 95 52
1-STORY HOUSE
Room
Average
Operating
Hours
(Manual
Switch)
2
Room Type
Distribution
3
Average # of
Fixtures per
room
Average # of
lamps per
room
1
Average
Lamp
Wattage
4
Total Room
Wattage
Average
Lamp
Wattage Total Wattage
GROUND FLOOR
Bedroom 1.60 3.00 0.90 1.48 58 257 23 102
Bathroom 1.50 2.00 1.40 5.00 58 580 14 140
Family Room 2.50 1.00 1.00 1.64 58 95 23 38
Halls/entry 1.60 1.00 0.80 1.31 58 76 15 20
Kitchen/Dining 3.50 1.00 3.10 5.08 23 117 23 117
Living Room 3.30 1.00 1.00 1.64 58 95 23 38
Laundry/Utility Room 1.20 1.00 1.00 1.64 58 95 23 38
TOTAL 1315 491
GARAGE
Garage 2.50 1.00 1.00 1.64 58 95 32 52
TOTAL 95 52
1. Based on an average number of lamps per fixture of 1.64 taken from California Energy Commission, Lighting Efficiency Technology Report, Volume 1 California
Baseline, September 1999, Page 2
2. KEMA Inc., CFL Metering Study, January 1, 2005, page 4-2
3. Room numbers and distribution chosen to represent a realistic residential home
4. California Energy Commission, Lighting Efficiency Technology Report, Volume 1 California Baseline, September 1999, page 4
Standard Efficiency High Efficiency
Standard Efficiency High Efficiency
92
Appendix C: Baseline eQuest Input File

INPUT ..

$ ---------------------------------------------------------
$ Abort, Diagnostics
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Global Parameters
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Title, Run Periods, Design Days, Holidays
$ ---------------------------------------------------------

TITLE
LINE-1 = *DEER Single Family*
..

"Entire Year" = RUN-PERIOD-PD
BEGIN-MONTH = 1
BEGIN-DAY = 1
BEGIN-YEAR = 1991
END-MONTH = 12
END-DAY = 31
END-YEAR = 1991
..

"Standard US Holidays" = HOLIDAYS
LIBRARY-ENTRY "US"
..

$ ---------------------------------------------------------
$ Compliance Data
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Site and Building Data
$ ---------------------------------------------------------

"Site Data" = SITE-PARAMETERS
ALTITUDE = 986
..

"Building Data" = BUILD-PARAMETERS
AZIMUTH = 90
HOLIDAYS = "Standard US Holidays"
..

93

$ ---------------------------------------------------------
$ Materials / Layers / Constructions
$ ---------------------------------------------------------

"EL1 EWall Cons Mat 2 (0.98)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.98
..
"EL1 Roof Cons Mat 4 (2.94)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 2.94
..
"EL1 IWall Cons Mat 2 (0.91)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.91
..
"EL1 IFlr Cons Mat 1 (0.031)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.031
..
"EL2 EWall Cons Mat 2 (0.98)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.98
..
"EL2 EWall R-val Material" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 15.81
..
"EL2 Roof Cons Mat 4 (0.29)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.29
..
"EL2 IWall Cons Mat 2 (0.91)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.91
..
"EL2 IFlr Cons Mat 1 (0.031)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.031
..
"EL2 AFlr Cons Mat 1 (0.25)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.25
..
"EL2 AFlr R-val Material" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 36.098
..
"EL3 EWall Cons Mat 2 (0.98)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.98
..
"EL3 Roof Cons Mat 4 (2.94)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 2.94
..
"EL3 IWall Cons Mat 2 (0.91)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.91
..
94
"EL3 IFlr Cons Mat 1 (0.031)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.031
..
"EL4 EWall Cons Mat 2 (0.98)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.98
..
"EL4 Roof Cons Mat 4 (2.94)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 2.94
..
"EL4 IWall Cons Mat 2 (0.91)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.91
..
"EL4 IFlr Cons Mat 1 (0.031)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.031
..
"EL5 EWall Cons Mat 2 (0.98)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.98
..
"EL5 EWall R-val Material" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 8.24
..
"EL5 Roof Cons Mat 4 (0.29)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.29
..
"EL5 IWall Cons Mat 2 (0.91)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.91
..
"EL5 IFlr Cons Mat 1 (0.031)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.031
..
"EL5 AFlr Cons Mat 1 (0.25)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.25
..
"EL5 AFlr R-val Material" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 23.34
..
"EL6 EWall Cons Mat 2 (0.98)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.98
..
"EL6 Roof Cons Mat 4 (2.94)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 2.94
..
"EL6 IWall Cons Mat 2 (0.91)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.91
..
"EL6 IFlr Cons Mat 1 (0.031)" = MATERIAL
TYPE = RESISTANCE
95
RESISTANCE = 0.031
..
"EL7 EWall Cons Mat 2 (0.98)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.98
..
"EL7 EWall R-val Material" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 15.81
..
"EL7 Roof Cons Mat 4 (0.29)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.29
..
"EL7 IWall Cons Mat 2 (0.91)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.91
..
"EL7 IFlr Cons Mat 1 (0.031)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.031
..
"EL7 AFlr Cons Mat 1 (0.25)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.25
..
"EL7 AFlr R-val Material" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 36.098
..
"EL8 EWall Cons Mat 2 (0.98)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.98
..
"EL8 EWall R-val Material" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 15.81
..
"EL8 Roof Cons Mat 4 (0.29)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.29
..
"EL8 IWall Cons Mat 2 (0.91)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.91
..
"EL8 IFlr Cons Mat 1 (0.031)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.031
..
"EL8 AFlr Cons Mat 1 (0.25)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.25
..
"EL8 AFlr R-val Material" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 36.098
..
"Floor abv Crawl Space M1" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.05
..
96
"Garage Int Wall M2" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.98
..
"Garage Int Wall FRV" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 14.9894
..
"Garage Ext Wall M3" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.98
..
"EL1 UFMat (G.1.U2.M1)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.417074
..
"EL2 UFMat (G.1.U2.M1)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 7.54935
..
"EL3 UFMat (G.1.U2.M1)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.417074
..
"EL4 UFMat (G.1.U2.M1)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.417074
..
"EL5 UFMat (G.1.U2.M1)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 7.54935
..
"EL6 UFMat (G.1.U2.M1)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 0.417074
..
"EL7 UFMat (G.S1.U2.M1)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 10.5167
..
"EL7 UFMat (G.N2.U3.M1)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 10.5167
..
"EL7 UFMat (G.S3.U4.M1)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 2.08612
..
"EL7 UFMat (G.N4.U5.M1)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 2.08612
..
"EL8 UFMat (G.W1.U2.M1)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 10.5167
..
"EL8 UFMat (G.E2.U3.M1)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 10.5167
..
"EL8 UFMat (G.W3.U4.M1)" = MATERIAL
TYPE = RESISTANCE
97
RESISTANCE = 2.08612
..
"EL8 UFMat (G.E4.U5.M1)" = MATERIAL
TYPE = RESISTANCE
RESISTANCE = 2.08612
..

"EL1 EWall Cons Layers" = LAYERS
MATERIAL = ( "Stucco 1in (SC01)", "Bldg Paper Felt (BP01)",
"EL1 EWall Cons Mat 2 (0.98)", "GypBd 1/2in (GP01)" )
..
"EL1 Roof Cons Layers" = LAYERS
MATERIAL = ( "ClayTile Paver 3/8in (CT11)",
"Blt-Up Roof 3/8in (BR01)", "Bldg Paper Felt (BP01)",
"Plywd 5/8in (PW04)", "EL1 Roof Cons Mat 4 (2.94)",
"MinWool Batt R30 (IN05)", "GypBd 5/8in (GP02)" )
..
"EL1 IWall Cons Layers" = LAYERS
MATERIAL = ( "GypBd 1/2in (GP01)", "EL1 IWall Cons Mat 2 (0.91)",
"GypBd 1/2in (GP01)" )
..
"EL1 IFlr Cons Layers" = LAYERS
MATERIAL = ( "EL1 IFlr Cons Mat 1 (0.031)", "Plywd 1in (PW06)",
"Carpet & Rubber Pad (CP02)" )
..
"EL2 EWall Cons Layers" = LAYERS
MATERIAL = ( "Stucco 1in (SC01)", "Bldg Paper Felt (BP01)",
"EL2 EWall R-val Material", "EL2 EWall Cons Mat 2 (0.98)",
"GypBd 1/2in (GP01)" )
..
"EL2 Roof Cons Layers" = LAYERS
MATERIAL = ( "ClayTile Paver 3/8in (CT11)",
"Blt-Up Roof 3/8in (BR01)", "Bldg Paper Felt (BP01)",
"Plywd 5/8in (PW04)", "EL2 Roof Cons Mat 4 (0.29)" )
..
"EL2 IWall Cons Layers" = LAYERS
MATERIAL = ( "GypBd 5/8in (GP02)", "EL2 IWall Cons Mat 2 (0.91)",
"GypBd 1/2in (GP01)" )
..
"EL2 IFlr Cons Layers" = LAYERS
MATERIAL = ( "EL2 IFlr Cons Mat 1 (0.031)", "Plywd 1in (PW06)",
"Carpet & Rubber Pad (CP02)" )
..
"EL2 AFlr Cons Layers" = LAYERS
MATERIAL = ( "EL2 AFlr Cons Mat 1 (0.25)",
"EL2 AFlr R-val Material", "GypBd 5/8in (GP02)" )
..
"EL3 EWall Cons Layers" = LAYERS
MATERIAL = ( "Stucco 1in (SC01)", "Bldg Paper Felt (BP01)",
"EL3 EWall Cons Mat 2 (0.98)", "GypBd 1/2in (GP01)" )
..
"EL3 Roof Cons Layers" = LAYERS
MATERIAL = ( "ClayTile Paver 3/8in (CT11)",
"Blt-Up Roof 3/8in (BR01)", "Bldg Paper Felt (BP01)",
"Plywd 5/8in (PW04)", "EL3 Roof Cons Mat 4 (2.94)",
"MinWool Batt R30 (IN05)", "GypBd 5/8in (GP02)" )
..
"EL3 IWall Cons Layers" = LAYERS
MATERIAL = ( "GypBd 1/2in (GP01)", "EL3 IWall Cons Mat 2 (0.91)",
"GypBd 1/2in (GP01)" )
..
"EL3 IFlr Cons Layers" = LAYERS
98
MATERIAL = ( "EL3 IFlr Cons Mat 1 (0.031)", "Plywd 1in (PW06)",
"Carpet & Rubber Pad (CP02)" )
..
"EL4 EWall Cons Layers" = LAYERS
MATERIAL = ( "Stucco 1in (SC01)", "Bldg Paper Felt (BP01)",
"EL4 EWall Cons Mat 2 (0.98)", "GypBd 1/2in (GP01)" )
..
"EL4 Roof Cons Layers" = LAYERS
MATERIAL = ( "ClayTile Paver 3/8in (CT11)",
"Blt-Up Roof 3/8in (BR01)", "Bldg Paper Felt (BP01)",
"Plywd 5/8in (PW04)", "EL4 Roof Cons Mat 4 (2.94)",
"MinWool Batt R30 (IN05)", "GypBd 5/8in (GP02)" )
..
"EL4 IWall Cons Layers" = LAYERS
MATERIAL = ( "GypBd 1/2in (GP01)", "EL4 IWall Cons Mat 2 (0.91)",
"GypBd 1/2in (GP01)" )
..
"EL4 IFlr Cons Layers" = LAYERS
MATERIAL = ( "EL4 IFlr Cons Mat 1 (0.031)", "Plywd 1in (PW06)",
"Carpet & Rubber Pad (CP02)" )
..
"EL5 EWall Cons Layers" = LAYERS
MATERIAL = ( "Stucco 1in (SC01)", "Bldg Paper Felt (BP01)",
"EL5 EWall R-val Material", "EL5 EWall Cons Mat 2 (0.98)",
"GypBd 1/2in (GP01)" )
..
"EL5 Roof Cons Layers" = LAYERS
MATERIAL = ( "ClayTile Paver 3/8in (CT11)",
"Blt-Up Roof 3/8in (BR01)", "Bldg Paper Felt (BP01)",
"Plywd 5/8in (PW04)", "EL5 Roof Cons Mat 4 (0.29)" )
..
"EL5 IWall Cons Layers" = LAYERS
MATERIAL = ( "GypBd 5/8in (GP02)", "EL5 IWall Cons Mat 2 (0.91)",
"GypBd 1/2in (GP01)" )
..
"EL5 IFlr Cons Layers" = LAYERS
MATERIAL = ( "EL5 IFlr Cons Mat 1 (0.031)", "Plywd 1in (PW06)",
"Carpet & Rubber Pad (CP02)" )
..
"EL5 AFlr Cons Layers" = LAYERS
MATERIAL = ( "EL5 AFlr Cons Mat 1 (0.25)",
"EL5 AFlr R-val Material", "GypBd 5/8in (GP02)" )
..
"EL6 EWall Cons Layers" = LAYERS
MATERIAL = ( "Stucco 1in (SC01)", "Bldg Paper Felt (BP01)",
"EL6 EWall Cons Mat 2 (0.98)", "GypBd 1/2in (GP01)" )
..
"EL6 Roof Cons Layers" = LAYERS
MATERIAL = ( "ClayTile Paver 3/8in (CT11)",
"Blt-Up Roof 3/8in (BR01)", "Bldg Paper Felt (BP01)",
"Plywd 5/8in (PW04)", "EL6 Roof Cons Mat 4 (2.94)",
"MinWool Batt R30 (IN05)", "GypBd 5/8in (GP02)" )
..
"EL6 IWall Cons Layers" = LAYERS
MATERIAL = ( "GypBd 1/2in (GP01)", "EL6 IWall Cons Mat 2 (0.91)",
"GypBd 1/2in (GP01)" )
..
"EL6 IFlr Cons Layers" = LAYERS
MATERIAL = ( "EL6 IFlr Cons Mat 1 (0.031)", "Plywd 1in (PW06)",
"Carpet & Rubber Pad (CP02)" )
..
"EL7 EWall Cons Layers" = LAYERS
99
MATERIAL = ( "Stucco 1in (SC01)", "Bldg Paper Felt (BP01)",
"EL7 EWall R-val Material", "EL7 EWall Cons Mat 2 (0.98)",
"GypBd 1/2in (GP01)" )
..
"EL7 Roof Cons Layers" = LAYERS
MATERIAL = ( "ClayTile Paver 3/8in (CT11)",
"Blt-Up Roof 3/8in (BR01)", "Bldg Paper Felt (BP01)",
"Plywd 5/8in (PW04)", "EL7 Roof Cons Mat 4 (0.29)" )
..
"EL7 IWall Cons Layers" = LAYERS
MATERIAL = ( "GypBd 5/8in (GP02)", "EL7 IWall Cons Mat 2 (0.91)",
"GypBd 1/2in (GP01)" )
..
"EL7 IFlr Cons Layers" = LAYERS
MATERIAL = ( "EL7 IFlr Cons Mat 1 (0.031)", "Plywd 1in (PW06)",
"Carpet & Rubber Pad (CP02)" )
..
"EL7 AFlr Cons Layers" = LAYERS
MATERIAL = ( "EL7 AFlr Cons Mat 1 (0.25)",
"EL7 AFlr R-val Material", "GypBd 5/8in (GP02)" )
..
"EL8 EWall Cons Layers" = LAYERS
MATERIAL = ( "Stucco 1in (SC01)", "Bldg Paper Felt (BP01)",
"EL8 EWall R-val Material", "EL8 EWall Cons Mat 2 (0.98)",
"GypBd 1/2in (GP01)" )
..
"EL8 Roof Cons Layers" = LAYERS
MATERIAL = ( "ClayTile Paver 3/8in (CT11)",
"Blt-Up Roof 3/8in (BR01)", "Bldg Paper Felt (BP01)",
"Plywd 5/8in (PW04)", "EL8 Roof Cons Mat 4 (0.29)" )
..
"EL8 IWall Cons Layers" = LAYERS
MATERIAL = ( "GypBd 5/8in (GP02)", "EL8 IWall Cons Mat 2 (0.91)",
"GypBd 1/2in (GP01)" )
..
"EL8 IFlr Cons Layers" = LAYERS
MATERIAL = ( "EL8 IFlr Cons Mat 1 (0.031)", "Plywd 1in (PW06)",
"Carpet & Rubber Pad (CP02)" )
..
"EL8 AFlr Cons Layers" = LAYERS
MATERIAL = ( "EL8 AFlr Cons Mat 1 (0.25)",
"EL8 AFlr R-val Material", "GypBd 5/8in (GP02)" )
..
"Floor abv Crawl Space Lyr" = LAYERS
INSIDE-FILM-RES = 0.92
MATERIAL = ( "Floor abv Crawl Space M1", "Plywd 1in (PW06)",
"Carpet & Rubber Pad (CP02)" )
..
"Crawl Space Floor Lyr" = LAYERS
INSIDE-FILM-RES = 0.92
MATERIAL = ( "Light Soil, Damp 12in" )
..
"Crawl Space Wall Lyr" = LAYERS
INSIDE-FILM-RES = 0.68
MATERIAL = ( "Light Soil, Damp 12in", "Conc HW 140lb 6in (CC04)" )
..
"Garage Int Wall Lyr" = LAYERS
INSIDE-FILM-RES = 0.68
MATERIAL = ( "GypBd 1/2in (GP01)", "Garage Int Wall M2",
"Garage Int Wall FRV", "GypBd 1/2in (GP01)" )
..
"Garage Ext Wall Lyr" = LAYERS
100
INSIDE-FILM-RES = 0.68
MATERIAL = ( "Stucco 1in (SC01)", "Bldg Paper Felt (BP01)",
"Garage Ext Wall M3", "GypBd 1/2in (GP01)" )
..
"EL1 UFLyrs (G.1.U2)" = LAYERS
MATERIAL = ( "EL1 UFMat (G.1.U2.M1)", "Light Soil, Damp 12in",
"Conc HW 140lb 4in (HF-C5)", "Carpet & Rubber Pad (CP02)" )
..
"EL2 UFLyrs (G.1.U2)" = LAYERS
MATERIAL = ( "EL2 UFMat (G.1.U2.M1)", "Light Soil, Damp 12in",
"Conc HW 140lb 4in (HF-C5)", "Carpet & Rubber Pad (CP02)" )
..
"EL3 UFLyrs (G.1.U2)" = LAYERS
MATERIAL = ( "EL3 UFMat (G.1.U2.M1)", "Light Soil, Damp 12in",
"Conc HW 140lb 4in (HF-C5)", "Carpet & Rubber Pad (CP02)" )
..
"EL4 UFLyrs (G.1.U2)" = LAYERS
MATERIAL = ( "EL4 UFMat (G.1.U2.M1)", "Light Soil, Damp 12in",
"Conc HW 140lb 4in (HF-C5)", "Carpet & Rubber Pad (CP02)" )
..
"EL5 UFLyrs (G.1.U2)" = LAYERS
MATERIAL = ( "EL5 UFMat (G.1.U2.M1)", "Light Soil, Damp 12in",
"Conc HW 140lb 4in (HF-C5)", "Carpet & Rubber Pad (CP02)" )
..
"EL6 UFLyrs (G.1.U2)" = LAYERS
MATERIAL = ( "EL6 UFMat (G.1.U2.M1)", "Light Soil, Damp 12in",
"Conc HW 140lb 4in (HF-C5)", "Carpet & Rubber Pad (CP02)" )
..
"EL7 UFLyrs (G.S1.U2)" = LAYERS
MATERIAL = ( "EL7 UFMat (G.S1.U2.M1)", "Light Soil, Damp 12in",
"Conc HW 140lb 4in (HF-C5)", "Carpet & Rubber Pad (CP02)" )
..
"EL7 UFLyrs (G.N2.U3)" = LAYERS
MATERIAL = ( "EL7 UFMat (G.N2.U3.M1)", "Light Soil, Damp 12in",
"Conc HW 140lb 4in (HF-C5)", "Carpet & Rubber Pad (CP02)" )
..
"EL7 UFLyrs (G.S3.U4)" = LAYERS
MATERIAL = ( "EL7 UFMat (G.S3.U4.M1)", "Light Soil, Damp 12in",
"Conc HW 140lb 4in (HF-C5)", "Carpet & Rubber Pad (CP02)" )
..
"EL7 UFLyrs (G.N4.U5)" = LAYERS
MATERIAL = ( "EL7 UFMat (G.N4.U5.M1)", "Light Soil, Damp 12in",
"Conc HW 140lb 4in (HF-C5)", "Carpet & Rubber Pad (CP02)" )
..
"EL8 UFLyrs (G.W1.U2)" = LAYERS
MATERIAL = ( "EL8 UFMat (G.W1.U2.M1)", "Light Soil, Damp 12in",
"Conc HW 140lb 4in (HF-C5)", "Carpet & Rubber Pad (CP02)" )
..
"EL8 UFLyrs (G.E2.U3)" = LAYERS
MATERIAL = ( "EL8 UFMat (G.E2.U3.M1)", "Light Soil, Damp 12in",
"Conc HW 140lb 4in (HF-C5)", "Carpet & Rubber Pad (CP02)" )
..
"EL8 UFLyrs (G.W3.U4)" = LAYERS
MATERIAL = ( "EL8 UFMat (G.W3.U4.M1)", "Light Soil, Damp 12in",
"Conc HW 140lb 4in (HF-C5)", "Carpet & Rubber Pad (CP02)" )
..
"EL8 UFLyrs (G.E4.U5)" = LAYERS
MATERIAL = ( "EL8 UFMat (G.E4.U5.M1)", "Light Soil, Damp 12in",
"Conc HW 140lb 4in (HF-C5)", "Carpet & Rubber Pad (CP02)" )
..

"EL1 EWall Construction" = CONSTRUCTION
101
TYPE = LAYERS
ABSORPTANCE = 0.6
ROUGHNESS = 1
LAYERS = "EL1 EWall Cons Layers"
..
"EL1 Roof Construction" = CONSTRUCTION
TYPE = LAYERS
ABSORPTANCE = 0.58
ROUGHNESS = 3
LAYERS = "EL1 Roof Cons Layers"
..
"EL1 IWall Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL1 IWall Cons Layers"
..
"EL1 IFlr Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL1 IFlr Cons Layers"
..
"EL2 EWall Construction" = CONSTRUCTION
TYPE = LAYERS
ABSORPTANCE = 0.6
ROUGHNESS = 1
LAYERS = "EL2 EWall Cons Layers"
..
"EL2 Roof Construction" = CONSTRUCTION
TYPE = LAYERS
ABSORPTANCE = 0.58
ROUGHNESS = 3
LAYERS = "EL2 Roof Cons Layers"
..
"EL2 IWall Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL2 IWall Cons Layers"
..
"EL2 IFlr Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL2 IFlr Cons Layers"
..
"EL2 AFlr Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL2 AFlr Cons Layers"
..
"EL3 EWall Construction" = CONSTRUCTION
TYPE = LAYERS
ABSORPTANCE = 0.6
ROUGHNESS = 1
LAYERS = "EL3 EWall Cons Layers"
..
"EL3 Roof Construction" = CONSTRUCTION
TYPE = LAYERS
ABSORPTANCE = 0.58
ROUGHNESS = 3
LAYERS = "EL3 Roof Cons Layers"
..
"EL3 IWall Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL3 IWall Cons Layers"
..
"EL3 IFlr Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL3 IFlr Cons Layers"
102
..
"EL4 EWall Construction" = CONSTRUCTION
TYPE = LAYERS
ABSORPTANCE = 0.6
ROUGHNESS = 1
LAYERS = "EL4 EWall Cons Layers"
..
"EL4 Roof Construction" = CONSTRUCTION
TYPE = LAYERS
ABSORPTANCE = 0.58
ROUGHNESS = 3
LAYERS = "EL4 Roof Cons Layers"
..
"EL4 IWall Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL4 IWall Cons Layers"
..
"EL4 IFlr Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL4 IFlr Cons Layers"
..
"EL5 EWall Construction" = CONSTRUCTION
TYPE = LAYERS
ABSORPTANCE = 0.6
ROUGHNESS = 1
LAYERS = "EL5 EWall Cons Layers"
..
"EL5 Roof Construction" = CONSTRUCTION
TYPE = LAYERS
ABSORPTANCE = 0.58
ROUGHNESS = 3
LAYERS = "EL5 Roof Cons Layers"
..
"EL5 IWall Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL5 IWall Cons Layers"
..
"EL5 IFlr Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL5 IFlr Cons Layers"
..
"EL5 AFlr Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL5 AFlr Cons Layers"
..
"EL6 EWall Construction" = CONSTRUCTION
TYPE = LAYERS
ABSORPTANCE = 0.6
ROUGHNESS = 1
LAYERS = "EL6 EWall Cons Layers"
..
"EL6 Roof Construction" = CONSTRUCTION
TYPE = LAYERS
ABSORPTANCE = 0.58
ROUGHNESS = 3
LAYERS = "EL6 Roof Cons Layers"
..
"EL6 IWall Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL6 IWall Cons Layers"
..
"EL6 IFlr Construction" = CONSTRUCTION
103
TYPE = LAYERS
LAYERS = "EL6 IFlr Cons Layers"
..
"EL7 EWall Construction" = CONSTRUCTION
TYPE = LAYERS
ABSORPTANCE = 0.6
ROUGHNESS = 1
LAYERS = "EL7 EWall Cons Layers"
..
"EL7 Roof Construction" = CONSTRUCTION
TYPE = LAYERS
ABSORPTANCE = 0.58
ROUGHNESS = 3
LAYERS = "EL7 Roof Cons Layers"
..
"EL7 IWall Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL7 IWall Cons Layers"
..
"EL7 IFlr Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL7 IFlr Cons Layers"
..
"EL7 AFlr Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL7 AFlr Cons Layers"
..
"EL8 EWall Construction" = CONSTRUCTION
TYPE = LAYERS
ABSORPTANCE = 0.6
ROUGHNESS = 1
LAYERS = "EL8 EWall Cons Layers"
..
"EL8 Roof Construction" = CONSTRUCTION
TYPE = LAYERS
ABSORPTANCE = 0.58
ROUGHNESS = 3
LAYERS = "EL8 Roof Cons Layers"
..
"EL8 IWall Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL8 IWall Cons Layers"
..
"EL8 IFlr Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL8 IFlr Cons Layers"
..
"EL8 AFlr Construction" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL8 AFlr Cons Layers"
..
"Floor abv Crawl Space" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "Floor abv Crawl Space Lyr"
..
"Crawl Space Floor" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "Crawl Space Floor Lyr"
..
"Crawl Space Wall" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "Crawl Space Wall Lyr"
104
..
"Garage Int Wall" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "Garage Int Wall Lyr"
..
"Garage Ext Wall" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "Garage Ext Wall Lyr"
..
"EL1 UFCons (G.1.U2)" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL1 UFLyrs (G.1.U2)"
..
"EL2 UFCons (G.1.U2)" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL2 UFLyrs (G.1.U2)"
..
"EL3 UFCons (G.1.U2)" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL3 UFLyrs (G.1.U2)"
..
"EL4 UFCons (G.1.U2)" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL4 UFLyrs (G.1.U2)"
..
"EL5 UFCons (G.1.U2)" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL5 UFLyrs (G.1.U2)"
..
"EL6 UFCons (G.1.U2)" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL6 UFLyrs (G.1.U2)"
..
"EL7 UFCons (G.S1.U2)" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL7 UFLyrs (G.S1.U2)"
..
"EL7 UFCons (G.N2.U3)" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL7 UFLyrs (G.N2.U3)"
..
"EL7 UFCons (G.S3.U4)" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL7 UFLyrs (G.S3.U4)"
..
"EL7 UFCons (G.N4.U5)" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL7 UFLyrs (G.N4.U5)"
..
"EL8 UFCons (G.W1.U2)" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL8 UFLyrs (G.W1.U2)"
..
"EL8 UFCons (G.E2.U3)" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL8 UFLyrs (G.E2.U3)"
..
"EL8 UFCons (G.W3.U4)" = CONSTRUCTION
TYPE = LAYERS
LAYERS = "EL8 UFLyrs (G.W3.U4)"
..
"EL8 UFCons (G.E4.U5)" = CONSTRUCTION
105
TYPE = LAYERS
LAYERS = "EL8 UFLyrs (G.E4.U5)"
..

$ ---------------------------------------------------------
$ Glass Type Codes
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Glass Types
$ ---------------------------------------------------------

"EL2 Window Type #1 GT" = GLASS-TYPE
TYPE = SHADING-COEF
SHADING-COEF = 0.45977
GLASS-CONDUCT = 0.642102
VIS-TRANS = 0.81
..
"EL5 Window Type #1 GT" = GLASS-TYPE
TYPE = SHADING-COEF
SHADING-COEF = 0.45977
GLASS-CONDUCT = 0.642102
VIS-TRANS = 0.81
..
"EL7 Window Type #1 GT" = GLASS-TYPE
TYPE = SHADING-COEF
SHADING-COEF = 0.45977
GLASS-CONDUCT = 0.642102
VIS-TRANS = 0.81
..
"EL8 Window Type #1 GT" = GLASS-TYPE
TYPE = SHADING-COEF
SHADING-COEF = 0.45977
GLASS-CONDUCT = 0.642102
VIS-TRANS = 0.81
..

$ ---------------------------------------------------------
$ Window Layers
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Lamps / Luminaries / Lighting Systems
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Day Schedules
$ ---------------------------------------------------------

"Lighting Schedule" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.04, 0.035, &D, 0.05, 0.075, 0.1, 0.09, 0.08, 0.075,
106
0.07, 0.06, 0.055, 0.05, &D, 0.06, 0.08, 0.11, 0.2, 0.275, 0.28,
0.225, 0.15, 0.09, 0.06 )
..
"EL1 Occ-1 S2 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0 )
..
"EL1 Occ-1 S3 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0 )
..
"EL2 Occ-2 S1 WD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0, &D, &D, &D, &D, &D, 0.5, 0.33, &D, &D, &D, &D, &D,
&D, &D, &D, &D, &D, 1, &D, &D, &D, 0.5, 0 )
..
"EL2 Occ-2 S1 WEH" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0, &D, &D, &D, &D, &D, &D, 0.5, 0.67, &D, &D, &D, &D,
&D, &D, &D, &D, 1, &D, &D, &D, &D, 0.5, 0 )
..
"EL2 Occ-2 S1 HDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0 )
..
"EL2 Occ-2 S1 CDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0, &D, &D, &D, &D, &D, &D, 0.5, 0.67, &D, &D, &D, &D,
&D, &D, &D, &D, 1, &D, &D, &D, &D, 0.5, 0 )
..
"EL2 Occ-2 S2 WD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0, &D, &D, &D, &D, &D, 0.5, 0.33, &D, &D, &D, &D, &D,
&D, &D, &D, &D, &D, 1, &D, &D, &D, 0.5, 0 )
..
"EL2 Occ-2 S2 WEH" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0, &D, &D, &D, &D, &D, &D, 0.5, 0.67, &D, &D, &D, &D,
&D, &D, &D, &D, 1, &D, &D, &D, &D, 0.5, 0 )
..
"EL2 Occ-2 S2 HDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0 )
..
"EL2 Occ-2 S2 CDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0, &D, &D, &D, &D, &D, &D, 0.5, 0.67, &D, &D, &D, &D,
&D, &D, &D, &D, 1, &D, &D, &D, &D, 0.5, 0 )
..
"EL2 Occ-2 S3 WD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0, &D, &D, &D, &D, &D, 0.5, 0.33, &D, &D, &D, &D, &D,
&D, &D, &D, &D, &D, 1, &D, &D, &D, 0.5, 0 )
..
"EL2 Occ-2 S3 WEH" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0, &D, &D, &D, &D, &D, &D, 0.5, 0.67, &D, &D, &D, &D,
&D, &D, &D, &D, 1, &D, &D, &D, &D, 0.5, 0 )
..
"EL2 Occ-2 S3 HDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0 )
107
..
"EL2 Occ-2 S3 CDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0, &D, &D, &D, &D, &D, &D, 0.5, 0.67, &D, &D, &D, &D,
&D, &D, &D, &D, 1, &D, &D, &D, &D, 0.5, 0 )
..
"EL2 Msc-2 S1 WD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.465, 0.315, 0.2775, 0.24, 0.2475, 0.24, 0.36,
0.4725, 0.5025, 0.5325, 0.6, 0.6525, 0.6225, 0.6, 0.5925, 0.585,
0.735, 0.8925, 0.93, 0.99, 0.9225, 0.8475, 0.7425, 0.63 )
..
"EL2 Msc-2 S1 WEH" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.4703, 0.3143, 0.2772, 0.24, &D, &D, 0.3589, 0.4703,
0.5001, 0.5298, 0.5892, 0.6487, 0.6189, 0.5966, 0.5892, 0.5818,
0.7304, 0.879, 0.9236, 0.983, 0.9161, 0.8344, 0.7378, 0.6189 )
..
"EL2 Msc-2 S1 HDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0 )
..
"EL2 Msc-2 S1 CDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.465, 0.315, 0.2775, 0.24, 0.2475, 0.24, 0.36,
0.4725, 0.5025, 0.5325, 0.6, 0.6525, 0.6225, 0.6, 0.5925, 0.585,
0.735, 0.8925, 0.93, 0.99, 0.9225, 0.8475, 0.7425, 0.63 )
..
"EL2 Msc-2 S2 WD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.4668, 0.2946, 0.2768, 0.253, 0.2649, 0.2946, 0.3718,
0.4371, 0.4847, 0.5381, &D, 0.5559, 0.5381, 0.5203, &D, 0.5262,
0.6213, 0.7163, 0.7104, 0.7163, 0.7876, 0.847, 0.7401, 0.645 )
..
"EL2 Msc-2 S2 WEH" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.4661, 0.2944, 0.2767, 0.253, 0.2648, 0.2944, 0.3714,
0.4365, 0.4839, 0.5372, 0.5431, 0.5608, 0.5372, 0.5194, 0.5253, &D,
0.62, 0.7148, 0.7088, 0.7207, 0.7917, 0.845, 0.7444, 0.6437 )
..
"EL2 Msc-2 S2 HDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0 )
..
"EL2 Msc-2 S2 CDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.4661, 0.2944, 0.2767, 0.253, 0.2648, 0.2944, 0.3714,
0.4365, 0.4839, 0.5372, 0.5431, 0.5608, 0.5372, 0.5194, 0.5253, &D,
0.62, 0.7148, 0.7088, 0.7207, 0.7917, 0.845, 0.7444, 0.6437 )
..
"EL2 Msc-2 S3 WD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.425, 0.295, 0.2625, 0.23, &D, &D, 0.3275, 0.425,
0.4575, 0.49, 0.542, 0.594, 0.5745, 0.555, 0.542, &D, 0.672, 0.802,
0.8345, 0.88, 0.8215, 0.7435, 0.659, 0.555 )
..
"EL2 Msc-2 S3 WEH" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.4728, 0.3266, 0.2918, 0.257, &D, &D, 0.3684, 0.4658,
0.5006, 0.5284, 0.5841, 0.6398, 0.612, 0.598, 0.5841, 0.5772,
0.7233, 0.8625, 0.9043, 0.953, 0.8904, 0.8138, 0.7233, 0.612 )
..
108
"EL2 Msc-2 S3 HDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0 )
..
"EL2 Msc-2 S3 CDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.4728, 0.3266, 0.2918, 0.257, &D, &D, 0.3684, 0.4658,
0.5006, 0.5284, 0.5841, 0.6398, 0.612, 0.598, 0.5841, 0.5772,
0.7233, 0.8625, 0.9043, 0.953, 0.8904, 0.8138, 0.7233, 0.612 )
..
"EL2 Occ-1 S1 WD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 1, &D, &D, &D, &D, &D, 0.5, 0.33, 0, &D, &D, &D, &D,
&D, &D, &D, &D, &D, &D, &D, &D, &D, 0.5, 1 )
..
"EL2 Occ-1 S1 WEH" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 1, &D, &D, &D, &D, &D, &D, 0.5, 0, &D, &D, &D, &D, &D,
&D, &D, &D, &D, &D, &D, &D, &D, 0.5, 1 )
..
"EL2 Occ-1 S1 HDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0 )
..
"EL2 Occ-1 S1 CDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 1, &D, &D, &D, &D, &D, &D, 0.5, 0, &D, &D, &D, &D, &D,
&D, &D, &D, &D, &D, &D, &D, &D, 0.5, 1 )
..
"EL2 Occ-1 S2 WD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 1, &D, &D, &D, &D, &D, 0.5, 0.33, 0, &D, &D, &D, &D,
&D, &D, &D, &D, &D, &D, &D, &D, &D, 0.5, 1 )
..
"EL2 Occ-1 S2 WEH" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 1, &D, &D, &D, &D, &D, &D, 0.5, 0, &D, &D, &D, &D, &D,
&D, &D, &D, &D, &D, &D, &D, &D, 0.5, 1 )
..
"EL2 Occ-1 S2 HDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0 )
..
"EL2 Occ-1 S2 CDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 1, &D, &D, &D, &D, &D, &D, 0.5, 0, &D, &D, &D, &D, &D,
&D, &D, &D, &D, &D, &D, &D, &D, 0.5, 1 )
..
"EL2 Occ-1 S3 WD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 1, &D, &D, &D, &D, &D, 0.5, 0.33, 0, &D, &D, &D, &D,
&D, &D, &D, &D, &D, &D, &D, &D, &D, 0.5, 1 )
..
"EL2 Occ-1 S3 WEH" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 1, &D, &D, &D, &D, &D, &D, 0.5, 0, &D, &D, &D, &D, &D,
&D, &D, &D, &D, &D, &D, &D, &D, 0.5, 1 )
..
"EL2 Occ-1 S3 HDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0 )
..
109
"EL2 Occ-1 S3 CDD" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 1, &D, &D, &D, &D, &D, &D, 0.5, 0, &D, &D, &D, &D, &D,
&D, &D, &D, &D, &D, &D, &D, &D, 0.5, 1 )
..
"EL7 Msc-3 S1 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0 )
..
"EL7 Msc-3 S2 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0 )
..
"EL7 Msc-3 S3 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0 )
..
"ZG6-S1 (PVVT) P-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG6-S1 (PVVT) P-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG6-S1 (PVVT) P-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG6-S1 (PVVT) C-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG6-S1 (PVVT) C-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG6-S1 (PVVT) C-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG7-S1 (PVVT) P-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG7-S1 (PVVT) P-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG7-S1 (PVVT) P-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG7-S1 (PVVT) C-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG7-S1 (PVVT) C-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG7-S1 (PVVT) C-Inf S3 All" = DAY-SCHEDULE-PD
110
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG8-S1 (PVVT) P-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG8-S1 (PVVT) P-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG8-S1 (PVVT) P-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG8-S1 (PVVT) C-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG8-S1 (PVVT) C-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG8-S1 (PVVT) C-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG9-S1 (PVVT) P-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG9-S1 (PVVT) P-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG9-S1 (PVVT) P-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG9-S1 (PVVT) C-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG9-S1 (PVVT) C-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG9-S1 (PVVT) C-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"S1 Sys1 (PVVT) Fan S1 All" = DAY-SCHEDULE-PD
TYPE = ON/OFF/FLAG
VALUES = ( 1 )
..
"S1 Sys1 (PVVT) Fan S2 All" = DAY-SCHEDULE-PD
TYPE = ON/OFF/FLAG
VALUES = ( 1 )
..
"S1 Sys1 (PVVT) Fan S3 All" = DAY-SCHEDULE-PD
TYPE = ON/OFF/FLAG
VALUES = ( 1 )
111
..
"ZG0-S1 (PVVT) P-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG0-S1 (PVVT) P-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG0-S1 (PVVT) P-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG0-S1 (PVVT) C-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG0-S1 (PVVT) C-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG0-S1 (PVVT) C-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG1-S1 (PVVT) P-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG1-S1 (PVVT) P-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG1-S1 (PVVT) P-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG1-S1 (PVVT) C-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG1-S1 (PVVT) C-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG1-S1 (PVVT) C-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG2-S1 (PVVT) P-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG2-S1 (PVVT) P-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG2-S1 (PVVT) P-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG2-S1 (PVVT) C-Inf S1 All" = DAY-SCHEDULE-PD
112
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG2-S1 (PVVT) C-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG2-S1 (PVVT) C-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"S2 Sys2 (PVVT) Fan S1 All" = DAY-SCHEDULE-PD
TYPE = ON/OFF/FLAG
VALUES = ( 1 )
..
"S2 Sys2 (PVVT) Fan S2 All" = DAY-SCHEDULE-PD
TYPE = ON/OFF/FLAG
VALUES = ( 1 )
..
"S2 Sys2 (PVVT) Fan S3 All" = DAY-SCHEDULE-PD
TYPE = ON/OFF/FLAG
VALUES = ( 1 )
..
"ZG10-S1 (PVVT) P-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG10-S1 (PVVT) P-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG10-S1 (PVVT) P-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG10-S1 (PVVT) C-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG10-S1 (PVVT) C-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG10-S1 (PVVT) C-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG11-S1 (PVVT) P-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG11-S1 (PVVT) P-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG11-S1 (PVVT) P-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG11-S1 (PVVT) C-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
113
..
"ZG11-S1 (PVVT) C-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG11-S1 (PVVT) C-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG12-S1 (PVVT) P-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG12-S1 (PVVT) P-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG12-S1 (PVVT) P-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG12-S1 (PVVT) C-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG12-S1 (PVVT) C-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG12-S1 (PVVT) C-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG13-S1 (PVVT) P-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG13-S1 (PVVT) P-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG13-S1 (PVVT) P-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG13-S1 (PVVT) C-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG13-S1 (PVVT) C-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG13-S1 (PVVT) C-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"S3 Sys3 (PVVT) Fan S1 All" = DAY-SCHEDULE-PD
TYPE = ON/OFF/FLAG
VALUES = ( 1 )
..
"S3 Sys3 (PVVT) Fan S2 All" = DAY-SCHEDULE-PD
114
TYPE = ON/OFF/FLAG
VALUES = ( 1 )
..
"S3 Sys3 (PVVT) Fan S3 All" = DAY-SCHEDULE-PD
TYPE = ON/OFF/FLAG
VALUES = ( 1 )
..
"ZG3-S1 (PVVT) P-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG3-S1 (PVVT) P-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG3-S1 (PVVT) P-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG3-S1 (PVVT) C-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG3-S1 (PVVT) C-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG3-S1 (PVVT) C-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG4-S1 (PVVT) P-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG4-S1 (PVVT) P-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG4-S1 (PVVT) P-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG4-S1 (PVVT) C-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG4-S1 (PVVT) C-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG4-S1 (PVVT) C-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG5-S1 (PVVT) P-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG5-S1 (PVVT) P-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
115
..
"ZG5-S1 (PVVT) P-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = MULTIPLIER
VALUES = ( 0.5 )
..
"ZG5-S1 (PVVT) C-Inf S1 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG5-S1 (PVVT) C-Inf S2 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"ZG5-S1 (PVVT) C-Inf S3 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.5 )
..
"S4 Sys4 (PVVT) Fan S1 All" = DAY-SCHEDULE-PD
TYPE = ON/OFF/FLAG
VALUES = ( 1 )
..
"S4 Sys4 (PVVT) Fan S2 All" = DAY-SCHEDULE-PD
TYPE = ON/OFF/FLAG
VALUES = ( 1 )
..
"S4 Sys4 (PVVT) Fan S3 All" = DAY-SCHEDULE-PD
TYPE = ON/OFF/FLAG
VALUES = ( 1 )
..
"DEER Demand Seas1 Day1" = DAY-SCHEDULE-PD
TYPE = ON/OFF
VALUES = ( 1 )
..
"DEER Demand Seas2 Day1" = DAY-SCHEDULE-PD
TYPE = ON/OFF
VALUES = ( 1, &D, &D, &D, &D, &D, &D, &D, &D, &D, &D, &D, &D, &D,
1, &D, &D, 1 )
..
"Lighting Schedule - Day" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0.04, 0.035, &D, 0.05, 0.075, 0.1, 0.09, 0.08, 0.075,
0.07, 0.06, 0.055, 0.05, 0.05, 0.06, 0.08, 0.11, 0.2, 0.275, 0.28,
0.225, 0.15, 0.09, 0.06 )
..
"EL1 Occ-1 S1 All" = DAY-SCHEDULE-PD
TYPE = FRACTION
VALUES = ( 0 )
..
"Day Schedule 1" = DAY-SCHEDULE-PD
TYPE = FLAG
VALUES = ( 1 )
..
"Day Schedule 2" = DAY-SCHEDULE-PD
TYPE = FLAG
VALUES = ( 2 )
..
"Day Schedule 3" = DAY-SCHEDULE-PD
TYPE = FLAG
VALUES = ( 3 )
..
"WD - Tariff TOU" = DAY-SCHEDULE-PD
TYPE = FLAG
116
VALUES = ( 1, &D, &D, &D, &D, &D, &D, &D, &D, &D, 2, &D, &D, &D,
&D, &D, &D, &D, 1 )
..
"WE - Tariff TOU" = DAY-SCHEDULE-PD
TYPE = FLAG
VALUES = ( 1, &D, &D, &D, &D, &D, &D, &D, &D, &D, 1, &D, &D, &D,
&D, &D, &D, &D, 1 )
..
"Buntine Cooling Summer" = DAY-SCHEDULE-PD
TYPE = TEMPERATURE
VALUES = ( 78, &D, &D, &D, &D, &D, &D, 83, &D, 83, &D, &D, &D,
82, 81, 80, 79, 78 )
..
"Buntine Cooling Winter" = DAY-SCHEDULE-PD
TYPE = TEMPERATURE
VALUES = ( 100 )
..
"Buntine Heating Winter" = DAY-SCHEDULE-PD
TYPE = TEMPERATURE
VALUES = ( 65, &D, &D, &D, &D, &D, &D, 68, &D, &D, &D, &D, &D,
&D, &D, &D, &D, &D, &D, &D, &D, &D, &D, 65 )
..
"Buntine Heating Summer" = DAY-SCHEDULE-PD
TYPE = TEMPERATURE
VALUES = ( 0 )
..

$ ---------------------------------------------------------
$ Week Schedules
$ ---------------------------------------------------------

"EL1 Occ-1 S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "EL1 Occ-1 S1 All" )
..
"EL1 Occ-1 S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "EL1 Occ-1 S2 All" )
..
"EL1 Occ-1 S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "EL1 Occ-1 S3 All" )
..
"EL2 Occ-2 S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "EL2 Occ-2 S1 WD", &D, &D, &D, &D, "EL2 Occ-2 S1 WEH",
&D, &D, "EL2 Occ-2 S1 HDD", "EL2 Occ-2 S1 CDD" )
..
"EL2 Occ-2 S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "EL2 Occ-2 S2 WD", &D, &D, &D, &D, "EL2 Occ-2 S2 WEH",
&D, &D, "EL2 Occ-2 S2 HDD", "EL2 Occ-2 S2 CDD" )
..
"EL2 Occ-2 S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "EL2 Occ-2 S3 WD", &D, &D, &D, &D, "EL2 Occ-2 S3 WEH",
&D, &D, "EL2 Occ-2 S3 HDD", "EL2 Occ-2 S3 CDD" )
..
"EL2 Msc-2 S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "EL2 Msc-2 S1 WD", &D, &D, &D, &D, "EL2 Msc-2 S1 WEH",
&D, &D, "EL2 Msc-2 S1 HDD", "EL2 Msc-2 S1 CDD" )
117
..
"EL2 Msc-2 S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "EL2 Msc-2 S2 WD", &D, &D, &D, &D, "EL2 Msc-2 S2 WEH",
&D, &D, "EL2 Msc-2 S2 HDD", "EL2 Msc-2 S2 CDD" )
..
"EL2 Msc-2 S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "EL2 Msc-2 S3 WD", &D, &D, &D, &D, "EL2 Msc-2 S3 WEH",
&D, &D, "EL2 Msc-2 S3 HDD", "EL2 Msc-2 S3 CDD" )
..
"EL2 Occ-1 S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "EL2 Occ-1 S1 WD", &D, &D, &D, &D, "EL2 Occ-1 S1 WEH",
&D, &D, "EL2 Occ-1 S1 HDD", "EL2 Occ-1 S1 CDD" )
..
"EL2 Occ-1 S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "EL2 Occ-1 S2 WD", &D, &D, &D, &D, "EL2 Occ-1 S2 WEH",
&D, &D, "EL2 Occ-1 S2 HDD", "EL2 Occ-1 S2 CDD" )
..
"EL2 Occ-1 S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "EL2 Occ-1 S3 WD", &D, &D, &D, &D, "EL2 Occ-1 S3 WEH",
&D, &D, "EL2 Occ-1 S3 HDD", "EL2 Occ-1 S3 CDD" )
..
"EL7 Msc-3 S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "EL7 Msc-3 S1 All" )
..
"EL7 Msc-3 S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "EL7 Msc-3 S2 All" )
..
"EL7 Msc-3 S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "EL7 Msc-3 S3 All" )
..
"ZG6-S1 (PVVT) P-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG6-S1 (PVVT) P-Inf S1 All" )
..
"ZG6-S1 (PVVT) P-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG6-S1 (PVVT) P-Inf S2 All" )
..
"ZG6-S1 (PVVT) P-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG6-S1 (PVVT) P-Inf S3 All" )
..
"ZG6-S1 (PVVT) C-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG6-S1 (PVVT) C-Inf S1 All" )
..
"ZG6-S1 (PVVT) C-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG6-S1 (PVVT) C-Inf S2 All" )
..
"ZG6-S1 (PVVT) C-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG6-S1 (PVVT) C-Inf S3 All" )
..
118
"ZG7-S1 (PVVT) P-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG7-S1 (PVVT) P-Inf S1 All" )
..
"ZG7-S1 (PVVT) P-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG7-S1 (PVVT) P-Inf S2 All" )
..
"ZG7-S1 (PVVT) P-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG7-S1 (PVVT) P-Inf S3 All" )
..
"ZG7-S1 (PVVT) C-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG7-S1 (PVVT) C-Inf S1 All" )
..
"ZG7-S1 (PVVT) C-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG7-S1 (PVVT) C-Inf S2 All" )
..
"ZG7-S1 (PVVT) C-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG7-S1 (PVVT) C-Inf S3 All" )
..
"ZG8-S1 (PVVT) P-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG8-S1 (PVVT) P-Inf S1 All" )
..
"ZG8-S1 (PVVT) P-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG8-S1 (PVVT) P-Inf S2 All" )
..
"ZG8-S1 (PVVT) P-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG8-S1 (PVVT) P-Inf S3 All" )
..
"ZG8-S1 (PVVT) C-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG8-S1 (PVVT) C-Inf S1 All" )
..
"ZG8-S1 (PVVT) C-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG8-S1 (PVVT) C-Inf S2 All" )
..
"ZG8-S1 (PVVT) C-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG8-S1 (PVVT) C-Inf S3 All" )
..
"ZG9-S1 (PVVT) P-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG9-S1 (PVVT) P-Inf S1 All" )
..
"ZG9-S1 (PVVT) P-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG9-S1 (PVVT) P-Inf S2 All" )
..
"ZG9-S1 (PVVT) P-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG9-S1 (PVVT) P-Inf S3 All" )
..
"ZG9-S1 (PVVT) C-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
119
DAY-SCHEDULES = ( "ZG9-S1 (PVVT) C-Inf S1 All" )
..
"ZG9-S1 (PVVT) C-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG9-S1 (PVVT) C-Inf S2 All" )
..
"ZG9-S1 (PVVT) C-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG9-S1 (PVVT) C-Inf S3 All" )
..
"S1 Sys1 (PVVT) Fan S1 Wk" = WEEK-SCHEDULE-PD
TYPE = ON/OFF/FLAG
DAY-SCHEDULES = ( "S1 Sys1 (PVVT) Fan S1 All" )
..
"S1 Sys1 (PVVT) Fan S2 Wk" = WEEK-SCHEDULE-PD
TYPE = ON/OFF/FLAG
DAY-SCHEDULES = ( "S1 Sys1 (PVVT) Fan S2 All" )
..
"S1 Sys1 (PVVT) Fan S3 Wk" = WEEK-SCHEDULE-PD
TYPE = ON/OFF/FLAG
DAY-SCHEDULES = ( "S1 Sys1 (PVVT) Fan S3 All" )
..
"ZG0-S1 (PVVT) P-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG0-S1 (PVVT) P-Inf S1 All" )
..
"ZG0-S1 (PVVT) P-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG0-S1 (PVVT) P-Inf S2 All" )
..
"ZG0-S1 (PVVT) P-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG0-S1 (PVVT) P-Inf S3 All" )
..
"ZG0-S1 (PVVT) C-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG0-S1 (PVVT) C-Inf S1 All" )
..
"ZG0-S1 (PVVT) C-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG0-S1 (PVVT) C-Inf S2 All" )
..
"ZG0-S1 (PVVT) C-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG0-S1 (PVVT) C-Inf S3 All" )
..
"ZG1-S1 (PVVT) P-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG1-S1 (PVVT) P-Inf S1 All" )
..
"ZG1-S1 (PVVT) P-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG1-S1 (PVVT) P-Inf S2 All" )
..
"ZG1-S1 (PVVT) P-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG1-S1 (PVVT) P-Inf S3 All" )
..
"ZG1-S1 (PVVT) C-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG1-S1 (PVVT) C-Inf S1 All" )
..
120
"ZG1-S1 (PVVT) C-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG1-S1 (PVVT) C-Inf S2 All" )
..
"ZG1-S1 (PVVT) C-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG1-S1 (PVVT) C-Inf S3 All" )
..
"ZG2-S1 (PVVT) P-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG2-S1 (PVVT) P-Inf S1 All" )
..
"ZG2-S1 (PVVT) P-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG2-S1 (PVVT) P-Inf S2 All" )
..
"ZG2-S1 (PVVT) P-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG2-S1 (PVVT) P-Inf S3 All" )
..
"ZG2-S1 (PVVT) C-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG2-S1 (PVVT) C-Inf S1 All" )
..
"ZG2-S1 (PVVT) C-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG2-S1 (PVVT) C-Inf S2 All" )
..
"ZG2-S1 (PVVT) C-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG2-S1 (PVVT) C-Inf S3 All" )
..
"S2 Sys2 (PVVT) Fan S1 Wk" = WEEK-SCHEDULE-PD
TYPE = ON/OFF/FLAG
DAY-SCHEDULES = ( "S2 Sys2 (PVVT) Fan S1 All" )
..
"S2 Sys2 (PVVT) Fan S2 Wk" = WEEK-SCHEDULE-PD
TYPE = ON/OFF/FLAG
DAY-SCHEDULES = ( "S2 Sys2 (PVVT) Fan S2 All" )
..
"S2 Sys2 (PVVT) Fan S3 Wk" = WEEK-SCHEDULE-PD
TYPE = ON/OFF/FLAG
DAY-SCHEDULES = ( "S2 Sys2 (PVVT) Fan S3 All" )
..
"ZG10-S1 (PVVT) P-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG10-S1 (PVVT) P-Inf S1 All" )
..
"ZG10-S1 (PVVT) P-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG10-S1 (PVVT) P-Inf S2 All" )
..
"ZG10-S1 (PVVT) P-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG10-S1 (PVVT) P-Inf S3 All" )
..
"ZG10-S1 (PVVT) C-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG10-S1 (PVVT) C-Inf S1 All" )
..
"ZG10-S1 (PVVT) C-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
121
DAY-SCHEDULES = ( "ZG10-S1 (PVVT) C-Inf S2 All" )
..
"ZG10-S1 (PVVT) C-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG10-S1 (PVVT) C-Inf S3 All" )
..
"ZG11-S1 (PVVT) P-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG11-S1 (PVVT) P-Inf S1 All" )
..
"ZG11-S1 (PVVT) P-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG11-S1 (PVVT) P-Inf S2 All" )
..
"ZG11-S1 (PVVT) P-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG11-S1 (PVVT) P-Inf S3 All" )
..
"ZG11-S1 (PVVT) C-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG11-S1 (PVVT) C-Inf S1 All" )
..
"ZG11-S1 (PVVT) C-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG11-S1 (PVVT) C-Inf S2 All" )
..
"ZG11-S1 (PVVT) C-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG11-S1 (PVVT) C-Inf S3 All" )
..
"ZG12-S1 (PVVT) P-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG12-S1 (PVVT) P-Inf S1 All" )
..
"ZG12-S1 (PVVT) P-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG12-S1 (PVVT) P-Inf S2 All" )
..
"ZG12-S1 (PVVT) P-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG12-S1 (PVVT) P-Inf S3 All" )
..
"ZG12-S1 (PVVT) C-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG12-S1 (PVVT) C-Inf S1 All" )
..
"ZG12-S1 (PVVT) C-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG12-S1 (PVVT) C-Inf S2 All" )
..
"ZG12-S1 (PVVT) C-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG12-S1 (PVVT) C-Inf S3 All" )
..
"ZG13-S1 (PVVT) P-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG13-S1 (PVVT) P-Inf S1 All" )
..
"ZG13-S1 (PVVT) P-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG13-S1 (PVVT) P-Inf S2 All" )
..
122
"ZG13-S1 (PVVT) P-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG13-S1 (PVVT) P-Inf S3 All" )
..
"ZG13-S1 (PVVT) C-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG13-S1 (PVVT) C-Inf S1 All" )
..
"ZG13-S1 (PVVT) C-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG13-S1 (PVVT) C-Inf S2 All" )
..
"ZG13-S1 (PVVT) C-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG13-S1 (PVVT) C-Inf S3 All" )
..
"S3 Sys3 (PVVT) Fan S1 Wk" = WEEK-SCHEDULE-PD
TYPE = ON/OFF/FLAG
DAY-SCHEDULES = ( "S3 Sys3 (PVVT) Fan S1 All" )
..
"S3 Sys3 (PVVT) Fan S2 Wk" = WEEK-SCHEDULE-PD
TYPE = ON/OFF/FLAG
DAY-SCHEDULES = ( "S3 Sys3 (PVVT) Fan S2 All" )
..
"S3 Sys3 (PVVT) Fan S3 Wk" = WEEK-SCHEDULE-PD
TYPE = ON/OFF/FLAG
DAY-SCHEDULES = ( "S3 Sys3 (PVVT) Fan S3 All" )
..
"ZG3-S1 (PVVT) P-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG3-S1 (PVVT) P-Inf S1 All" )
..
"ZG3-S1 (PVVT) P-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG3-S1 (PVVT) P-Inf S2 All" )
..
"ZG3-S1 (PVVT) P-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG3-S1 (PVVT) P-Inf S3 All" )
..
"ZG3-S1 (PVVT) C-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG3-S1 (PVVT) C-Inf S1 All" )
..
"ZG3-S1 (PVVT) C-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG3-S1 (PVVT) C-Inf S2 All" )
..
"ZG3-S1 (PVVT) C-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG3-S1 (PVVT) C-Inf S3 All" )
..
"ZG4-S1 (PVVT) P-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG4-S1 (PVVT) P-Inf S1 All" )
..
"ZG4-S1 (PVVT) P-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG4-S1 (PVVT) P-Inf S2 All" )
..
"ZG4-S1 (PVVT) P-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
123
DAY-SCHEDULES = ( "ZG4-S1 (PVVT) P-Inf S3 All" )
..
"ZG4-S1 (PVVT) C-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG4-S1 (PVVT) C-Inf S1 All" )
..
"ZG4-S1 (PVVT) C-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG4-S1 (PVVT) C-Inf S2 All" )
..
"ZG4-S1 (PVVT) C-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG4-S1 (PVVT) C-Inf S3 All" )
..
"ZG5-S1 (PVVT) P-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG5-S1 (PVVT) P-Inf S1 All" )
..
"ZG5-S1 (PVVT) P-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG5-S1 (PVVT) P-Inf S2 All" )
..
"ZG5-S1 (PVVT) P-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = MULTIPLIER
DAY-SCHEDULES = ( "ZG5-S1 (PVVT) P-Inf S3 All" )
..
"ZG5-S1 (PVVT) C-Inf S1 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG5-S1 (PVVT) C-Inf S1 All" )
..
"ZG5-S1 (PVVT) C-Inf S2 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG5-S1 (PVVT) C-Inf S2 All" )
..
"ZG5-S1 (PVVT) C-Inf S3 Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "ZG5-S1 (PVVT) C-Inf S3 All" )
..
"S4 Sys4 (PVVT) Fan S1 Wk" = WEEK-SCHEDULE-PD
TYPE = ON/OFF/FLAG
DAY-SCHEDULES = ( "S4 Sys4 (PVVT) Fan S1 All" )
..
"S4 Sys4 (PVVT) Fan S2 Wk" = WEEK-SCHEDULE-PD
TYPE = ON/OFF/FLAG
DAY-SCHEDULES = ( "S4 Sys4 (PVVT) Fan S2 All" )
..
"S4 Sys4 (PVVT) Fan S3 Wk" = WEEK-SCHEDULE-PD
TYPE = ON/OFF/FLAG
DAY-SCHEDULES = ( "S4 Sys4 (PVVT) Fan S3 All" )
..
"DEER Demand Seas1 Week" = WEEK-SCHEDULE-PD
TYPE = ON/OFF
DAY-SCHEDULES = ( "DEER Demand Seas1 Day1" )
..
"DEER Demand Seas2 Week" = WEEK-SCHEDULE-PD
TYPE = ON/OFF
DAY-SCHEDULES = ( "DEER Demand Seas2 Day1" )
..
"Lighting Schedule - Wk" = WEEK-SCHEDULE-PD
TYPE = FRACTION
DAY-SCHEDULES = ( "Lighting Schedule", &D, &D, &D, &D,
"Lighting Schedule" )
124
..
"Week Schedule 1" = WEEK-SCHEDULE-PD
TYPE = FLAG
DAY-SCHEDULES = ( "Day Schedule 1" )
..
"Week Schedule 2" = WEEK-SCHEDULE-PD
TYPE = FLAG
DAY-SCHEDULES = ( "Day Schedule 2" )
..
"Week Schedule 3" = WEEK-SCHEDULE-PD
TYPE = FLAG
DAY-SCHEDULES = ( "Day Schedule 3" )
..
"Week - TOU Tariff" = WEEK-SCHEDULE-PD
TYPE = FLAG
DAY-SCHEDULES = ( "WD - Tariff TOU", &D, &D, &D, &D, "WE - Tariff TOU",
&D, "WE - Tariff TOU" )
..
"Buntine Heating Winter Wk" = WEEK-SCHEDULE-PD
TYPE = TEMPERATURE
DAY-SCHEDULES = ( "Buntine Heating Winter", &D, &D, &D, &D,
"Buntine Heating Winter" )
..
"Buntine Heating Summer Wk" = WEEK-SCHEDULE-PD
TYPE = TEMPERATURE
DAY-SCHEDULES = ( "Buntine Heating Summer", &D, &D, &D, &D,
"Buntine Heating Summer" )
..
"Buntine Cooling Winter Wk" = WEEK-SCHEDULE-PD
TYPE = TEMPERATURE
DAY-SCHEDULES = ( "Buntine Cooling Winter", &D, &D, &D, &D,
"Buntine Cooling Winter" )
..
"Buntine Cooling Summer Wk" = WEEK-SCHEDULE-PD
TYPE = TEMPERATURE
DAY-SCHEDULES = ( "Buntine Cooling Summer", &D, &D, &D, &D,
"Buntine Cooling Summer" )
..

$ ---------------------------------------------------------
$ Annual Schedules
$ ---------------------------------------------------------

"EL1 Occ-1 Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "EL1 Occ-1 S1 Wk", "EL1 Occ-1 S3 Wk",
"EL1 Occ-1 S2 Wk", "EL1 Occ-1 S3 Wk", "EL1 Occ-1 S1 Wk" )
..
"EL2 Occ-2 Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "EL2 Occ-2 S1 Wk", "EL2 Occ-2 S3 Wk",
"EL2 Occ-2 S2 Wk", "EL2 Occ-2 S3 Wk", "EL2 Occ-2 S1 Wk" )
..
"EL2 Msc-2 Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "EL2 Msc-2 S1 Wk", "EL2 Msc-2 S3 Wk",
125
"EL2 Msc-2 S2 Wk", "EL2 Msc-2 S3 Wk", "EL2 Msc-2 S1 Wk" )
..
"EL2 Occ-1 Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "EL2 Occ-1 S1 Wk", "EL2 Occ-1 S3 Wk",
"EL2 Occ-1 S2 Wk", "EL2 Occ-1 S3 Wk", "EL2 Occ-1 S1 Wk" )
..
"EL7 Msc-3 Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "EL7 Msc-3 S1 Wk", "EL7 Msc-3 S3 Wk",
"EL7 Msc-3 S2 Wk", "EL7 Msc-3 S3 Wk", "EL7 Msc-3 S1 Wk" )
..
"ZG6-S1 (PVVT) P-Inf Sch" = SCHEDULE-PD
TYPE = MULTIPLIER
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG6-S1 (PVVT) P-Inf S1 Wk",
"ZG6-S1 (PVVT) P-Inf S3 Wk", "ZG6-S1 (PVVT) P-Inf S2 Wk",
"ZG6-S1 (PVVT) P-Inf S3 Wk", "ZG6-S1 (PVVT) P-Inf S1 Wk" )
..
"ZG6-S1 (PVVT) C-Inf Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG6-S1 (PVVT) C-Inf S1 Wk",
"ZG6-S1 (PVVT) C-Inf S3 Wk", "ZG6-S1 (PVVT) C-Inf S2 Wk",
"ZG6-S1 (PVVT) C-Inf S3 Wk", "ZG6-S1 (PVVT) C-Inf S1 Wk" )
..
"ZG7-S1 (PVVT) P-Inf Sch" = SCHEDULE-PD
TYPE = MULTIPLIER
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG7-S1 (PVVT) P-Inf S1 Wk",
"ZG7-S1 (PVVT) P-Inf S3 Wk", "ZG7-S1 (PVVT) P-Inf S2 Wk",
"ZG7-S1 (PVVT) P-Inf S3 Wk", "ZG7-S1 (PVVT) P-Inf S1 Wk" )
..
"ZG7-S1 (PVVT) C-Inf Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG7-S1 (PVVT) C-Inf S1 Wk",
"ZG7-S1 (PVVT) C-Inf S3 Wk", "ZG7-S1 (PVVT) C-Inf S2 Wk",
"ZG7-S1 (PVVT) C-Inf S3 Wk", "ZG7-S1 (PVVT) C-Inf S1 Wk" )
..
"ZG8-S1 (PVVT) P-Inf Sch" = SCHEDULE-PD
TYPE = MULTIPLIER
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG8-S1 (PVVT) P-Inf S1 Wk",
"ZG8-S1 (PVVT) P-Inf S3 Wk", "ZG8-S1 (PVVT) P-Inf S2 Wk",
"ZG8-S1 (PVVT) P-Inf S3 Wk", "ZG8-S1 (PVVT) P-Inf S1 Wk" )
..
"ZG8-S1 (PVVT) C-Inf Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG8-S1 (PVVT) C-Inf S1 Wk",
"ZG8-S1 (PVVT) C-Inf S3 Wk", "ZG8-S1 (PVVT) C-Inf S2 Wk",
126
"ZG8-S1 (PVVT) C-Inf S3 Wk", "ZG8-S1 (PVVT) C-Inf S1 Wk" )
..
"ZG9-S1 (PVVT) P-Inf Sch" = SCHEDULE-PD
TYPE = MULTIPLIER
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG9-S1 (PVVT) P-Inf S1 Wk",
"ZG9-S1 (PVVT) P-Inf S3 Wk", "ZG9-S1 (PVVT) P-Inf S2 Wk",
"ZG9-S1 (PVVT) P-Inf S3 Wk", "ZG9-S1 (PVVT) P-Inf S1 Wk" )
..
"ZG9-S1 (PVVT) C-Inf Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG9-S1 (PVVT) C-Inf S1 Wk",
"ZG9-S1 (PVVT) C-Inf S3 Wk", "ZG9-S1 (PVVT) C-Inf S2 Wk",
"ZG9-S1 (PVVT) C-Inf S3 Wk", "ZG9-S1 (PVVT) C-Inf S1 Wk" )
..
"S1 Sys1 (PVVT) Fan Sch" = SCHEDULE-PD
TYPE = ON/OFF/FLAG
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "S1 Sys1 (PVVT) Fan S1 Wk",
"S1 Sys1 (PVVT) Fan S3 Wk", "S1 Sys1 (PVVT) Fan S2 Wk",
"S1 Sys1 (PVVT) Fan S3 Wk", "S1 Sys1 (PVVT) Fan S1 Wk" )
..
"ZG0-S1 (PVVT) P-Inf Sch" = SCHEDULE-PD
TYPE = MULTIPLIER
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG0-S1 (PVVT) P-Inf S1 Wk",
"ZG0-S1 (PVVT) P-Inf S3 Wk", "ZG0-S1 (PVVT) P-Inf S2 Wk",
"ZG0-S1 (PVVT) P-Inf S3 Wk", "ZG0-S1 (PVVT) P-Inf S1 Wk" )
..
"ZG0-S1 (PVVT) C-Inf Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG0-S1 (PVVT) C-Inf S1 Wk",
"ZG0-S1 (PVVT) C-Inf S3 Wk", "ZG0-S1 (PVVT) C-Inf S2 Wk",
"ZG0-S1 (PVVT) C-Inf S3 Wk", "ZG0-S1 (PVVT) C-Inf S1 Wk" )
..
"ZG1-S1 (PVVT) P-Inf Sch" = SCHEDULE-PD
TYPE = MULTIPLIER
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG1-S1 (PVVT) P-Inf S1 Wk",
"ZG1-S1 (PVVT) P-Inf S3 Wk", "ZG1-S1 (PVVT) P-Inf S2 Wk",
"ZG1-S1 (PVVT) P-Inf S3 Wk", "ZG1-S1 (PVVT) P-Inf S1 Wk" )
..
"ZG1-S1 (PVVT) C-Inf Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG1-S1 (PVVT) C-Inf S1 Wk",
"ZG1-S1 (PVVT) C-Inf S3 Wk", "ZG1-S1 (PVVT) C-Inf S2 Wk",
"ZG1-S1 (PVVT) C-Inf S3 Wk", "ZG1-S1 (PVVT) C-Inf S1 Wk" )
..
"ZG2-S1 (PVVT) P-Inf Sch" = SCHEDULE-PD
TYPE = MULTIPLIER
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
127
WEEK-SCHEDULES = ( "ZG2-S1 (PVVT) P-Inf S1 Wk",
"ZG2-S1 (PVVT) P-Inf S3 Wk", "ZG2-S1 (PVVT) P-Inf S2 Wk",
"ZG2-S1 (PVVT) P-Inf S3 Wk", "ZG2-S1 (PVVT) P-Inf S1 Wk" )
..
"ZG2-S1 (PVVT) C-Inf Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG2-S1 (PVVT) C-Inf S1 Wk",
"ZG2-S1 (PVVT) C-Inf S3 Wk", "ZG2-S1 (PVVT) C-Inf S2 Wk",
"ZG2-S1 (PVVT) C-Inf S3 Wk", "ZG2-S1 (PVVT) C-Inf S1 Wk" )
..
"S2 Sys2 (PVVT) Fan Sch" = SCHEDULE-PD
TYPE = ON/OFF/FLAG
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "S2 Sys2 (PVVT) Fan S1 Wk",
"S2 Sys2 (PVVT) Fan S3 Wk", "S2 Sys2 (PVVT) Fan S2 Wk",
"S2 Sys2 (PVVT) Fan S3 Wk", "S2 Sys2 (PVVT) Fan S1 Wk" )
..
"ZG10-S1 (PVVT) P-Inf Sch" = SCHEDULE-PD
TYPE = MULTIPLIER
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG10-S1 (PVVT) P-Inf S1 Wk",
"ZG10-S1 (PVVT) P-Inf S3 Wk", "ZG10-S1 (PVVT) P-Inf S2 Wk",
"ZG10-S1 (PVVT) P-Inf S3 Wk", "ZG10-S1 (PVVT) P-Inf S1 Wk" )
..
"ZG10-S1 (PVVT) C-Inf Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG10-S1 (PVVT) C-Inf S1 Wk",
"ZG10-S1 (PVVT) C-Inf S3 Wk", "ZG10-S1 (PVVT) C-Inf S2 Wk",
"ZG10-S1 (PVVT) C-Inf S3 Wk", "ZG10-S1 (PVVT) C-Inf S1 Wk" )
..
"ZG11-S1 (PVVT) P-Inf Sch" = SCHEDULE-PD
TYPE = MULTIPLIER
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG11-S1 (PVVT) P-Inf S1 Wk",
"ZG11-S1 (PVVT) P-Inf S3 Wk", "ZG11-S1 (PVVT) P-Inf S2 Wk",
"ZG11-S1 (PVVT) P-Inf S3 Wk", "ZG11-S1 (PVVT) P-Inf S1 Wk" )
..
"ZG11-S1 (PVVT) C-Inf Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG11-S1 (PVVT) C-Inf S1 Wk",
"ZG11-S1 (PVVT) C-Inf S3 Wk", "ZG11-S1 (PVVT) C-Inf S2 Wk",
"ZG11-S1 (PVVT) C-Inf S3 Wk", "ZG11-S1 (PVVT) C-Inf S1 Wk" )
..
"ZG12-S1 (PVVT) P-Inf Sch" = SCHEDULE-PD
TYPE = MULTIPLIER
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG12-S1 (PVVT) P-Inf S1 Wk",
"ZG12-S1 (PVVT) P-Inf S3 Wk", "ZG12-S1 (PVVT) P-Inf S2 Wk",
"ZG12-S1 (PVVT) P-Inf S3 Wk", "ZG12-S1 (PVVT) P-Inf S1 Wk" )
..
"ZG12-S1 (PVVT) C-Inf Sch" = SCHEDULE-PD
TYPE = FRACTION
128
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG12-S1 (PVVT) C-Inf S1 Wk",
"ZG12-S1 (PVVT) C-Inf S3 Wk", "ZG12-S1 (PVVT) C-Inf S2 Wk",
"ZG12-S1 (PVVT) C-Inf S3 Wk", "ZG12-S1 (PVVT) C-Inf S1 Wk" )
..
"ZG13-S1 (PVVT) P-Inf Sch" = SCHEDULE-PD
TYPE = MULTIPLIER
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG13-S1 (PVVT) P-Inf S1 Wk",
"ZG13-S1 (PVVT) P-Inf S3 Wk", "ZG13-S1 (PVVT) P-Inf S2 Wk",
"ZG13-S1 (PVVT) P-Inf S3 Wk", "ZG13-S1 (PVVT) P-Inf S1 Wk" )
..
"ZG13-S1 (PVVT) C-Inf Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG13-S1 (PVVT) C-Inf S1 Wk",
"ZG13-S1 (PVVT) C-Inf S3 Wk", "ZG13-S1 (PVVT) C-Inf S2 Wk",
"ZG13-S1 (PVVT) C-Inf S3 Wk", "ZG13-S1 (PVVT) C-Inf S1 Wk" )
..
"S3 Sys3 (PVVT) Fan Sch" = SCHEDULE-PD
TYPE = ON/OFF/FLAG
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "S3 Sys3 (PVVT) Fan S1 Wk",
"S3 Sys3 (PVVT) Fan S3 Wk", "S3 Sys3 (PVVT) Fan S2 Wk",
"S3 Sys3 (PVVT) Fan S3 Wk", "S3 Sys3 (PVVT) Fan S1 Wk" )
..
"ZG3-S1 (PVVT) P-Inf Sch" = SCHEDULE-PD
TYPE = MULTIPLIER
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG3-S1 (PVVT) P-Inf S1 Wk",
"ZG3-S1 (PVVT) P-Inf S3 Wk", "ZG3-S1 (PVVT) P-Inf S2 Wk",
"ZG3-S1 (PVVT) P-Inf S3 Wk", "ZG3-S1 (PVVT) P-Inf S1 Wk" )
..
"ZG3-S1 (PVVT) C-Inf Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG3-S1 (PVVT) C-Inf S1 Wk",
"ZG3-S1 (PVVT) C-Inf S3 Wk", "ZG3-S1 (PVVT) C-Inf S2 Wk",
"ZG3-S1 (PVVT) C-Inf S3 Wk", "ZG3-S1 (PVVT) C-Inf S1 Wk" )
..
"ZG4-S1 (PVVT) P-Inf Sch" = SCHEDULE-PD
TYPE = MULTIPLIER
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG4-S1 (PVVT) P-Inf S1 Wk",
"ZG4-S1 (PVVT) P-Inf S3 Wk", "ZG4-S1 (PVVT) P-Inf S2 Wk",
"ZG4-S1 (PVVT) P-Inf S3 Wk", "ZG4-S1 (PVVT) P-Inf S1 Wk" )
..
"ZG4-S1 (PVVT) C-Inf Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG4-S1 (PVVT) C-Inf S1 Wk",
"ZG4-S1 (PVVT) C-Inf S3 Wk", "ZG4-S1 (PVVT) C-Inf S2 Wk",
"ZG4-S1 (PVVT) C-Inf S3 Wk", "ZG4-S1 (PVVT) C-Inf S1 Wk" )
..
129
"ZG5-S1 (PVVT) P-Inf Sch" = SCHEDULE-PD
TYPE = MULTIPLIER
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG5-S1 (PVVT) P-Inf S1 Wk",
"ZG5-S1 (PVVT) P-Inf S3 Wk", "ZG5-S1 (PVVT) P-Inf S2 Wk",
"ZG5-S1 (PVVT) P-Inf S3 Wk", "ZG5-S1 (PVVT) P-Inf S1 Wk" )
..
"ZG5-S1 (PVVT) C-Inf Sch" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "ZG5-S1 (PVVT) C-Inf S1 Wk",
"ZG5-S1 (PVVT) C-Inf S3 Wk", "ZG5-S1 (PVVT) C-Inf S2 Wk",
"ZG5-S1 (PVVT) C-Inf S3 Wk", "ZG5-S1 (PVVT) C-Inf S1 Wk" )
..
"S4 Sys4 (PVVT) Fan Sch" = SCHEDULE-PD
TYPE = ON/OFF/FLAG
MONTH = ( 2, 3, 9, 11, 12 )
DAY = ( 28, 31, 30, 30, 31 )
WEEK-SCHEDULES = ( "S4 Sys4 (PVVT) Fan S1 Wk",
"S4 Sys4 (PVVT) Fan S3 Wk", "S4 Sys4 (PVVT) Fan S2 Wk",
"S4 Sys4 (PVVT) Fan S3 Wk", "S4 Sys4 (PVVT) Fan S1 Wk" )
..
"DEER Demand Season Sched" = SCHEDULE-PD
TYPE = ON/OFF
MONTH = ( 8, 8, 12 )
DAY = ( 11, 14, 31 )
WEEK-SCHEDULES = ( "DEER Demand Seas1 Week", "DEER Demand Seas2 Week",
"DEER Demand Seas1 Week" )
..
"Lighting - Annual" = SCHEDULE-PD
TYPE = FRACTION
MONTH = ( 12 )
DAY = ( 31 )
WEEK-SCHEDULES = ( "Lighting Schedule - Wk" )
..
"SCE Winter/Summer Schedule" = SCHEDULE-PD
TYPE = FLAG
MONTH = ( 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12 )
DAY = ( 31, 28, 31, 30, 31, 30, 31, 31, 30, 31, 30, 31 )
WEEK-SCHEDULES = ( "Week Schedule 3", "Week Schedule 1",
"Week Schedule 3", "Week Schedule 2", "Week Schedule 3",
"Week Schedule 2", "Week Schedule 3", "Week Schedule 3",
"Week Schedule 2", "Week Schedule 3", "Week Schedule 2",
"Week Schedule 3" )
..
"TOU Tariff" = SCHEDULE-PD
TYPE = FLAG
MONTH = ( 12 )
DAY = ( 31 )
WEEK-SCHEDULES = ( "Week - TOU Tariff" )
..
"Buntine Thermostat Cooling" = SCHEDULE-PD
TYPE = TEMPERATURE
MONTH = ( 4, 11, 12 )
DAY = ( 29, 1, 31 )
WEEK-SCHEDULES = ( "Buntine Cooling Winter Wk",
"Buntine Cooling Summer Wk", "Buntine Cooling Winter Wk" )
..
"DEER Res Cooling Tstat CZ10" = SCHEDULE-PD
TYPE = TEMPERATURE
130
MONTH = ( 12 )
DAY = ( 31 )
WEEK-SCHEDULES = ( "DEER HeatMode CoolTstat Week" )
..
"Buntine Thermostat Heating" = SCHEDULE-PD
TYPE = TEMPERATURE
MONTH = ( 4, 11, 12 )
DAY = ( 29, 1, 31 )
WEEK-SCHEDULES = ( "Buntine Heating Winter Wk",
"Buntine Heating Summer Wk", "Buntine Heating Winter Wk" )
..

$ ---------------------------------------------------------
$ Polygons
$ ---------------------------------------------------------

"EL1 Floor Polygon" = POLYGON
V1 = ( 0, 0 )
V2 = ( 0, 14 )
V3 = ( -15.23, 14 )
V4 = ( -15.23, 0 )
..
"EL2 Floor Polygon" = POLYGON
V1 = ( 0, 0 )
V2 = ( 0, 45.7 )
V3 = ( -30.46, 45.7 )
V4 = ( -30.46, 0 )
..
"EL2 Roof Polygon 1" = POLYGON
V1 = ( 2, -2 )
V2 = ( 2, 47.7 )
V3 = ( -32.46, 47.7 )
V4 = ( -32.46, -2 )
..
"EL2 Roof Polygon 1 Wall 1" = POLYGON
V1 = ( 0, 0 )
V2 = ( 45.7, 0 )
V3 = ( 45.7, 30.46 )
V4 = ( 0, 30.46 )
..
"EL2 Roof Polygon 2" = POLYGON
V1 = ( 2, -2 )
V2 = ( 2, 47.7 )
V3 = ( -32.46, 47.7 )
V4 = ( -32.46, -2 )
..
"EL2 Roof Polygon 2 Wall 1" = POLYGON
V1 = ( 0, 0 )
V2 = ( 49.7, 0 )
V3 = ( 49.7, 19.01 )
V4 = ( 0, 19.01 )
..
"EL2 Roof Polygon 2 Wall 2" = POLYGON
V1 = ( 0, 0 )
V2 = ( 45.7, 0 )
V3 = ( 45.7, 2 )
V4 = ( 0, 2 )
..
"EL2 Roof Polygon 2 Wall 3" = POLYGON
V1 = ( 0, 0 )
V2 = ( 34.46, 0 )
131
V3 = ( 17.23, 8.04 )
..
"EL2 Roof Polygon 2 Wall 4" = POLYGON
V1 = ( 0, 0 )
V2 = ( 49.7, 0 )
V3 = ( 49.7, 19.01 )
V4 = ( 0, 19.01 )
..
"EL2 Roof Polygon 2 Wall 5" = POLYGON
V1 = ( 0, 0 )
V2 = ( 45.7, 0 )
V3 = ( 45.7, 2 )
V4 = ( 0, 2 )
..
"EL2 Roof Polygon 2 Wall 6" = POLYGON
V1 = ( 0, 0 )
V2 = ( 34.46, 0 )
V3 = ( 17.23, 8.04 )
..
"EL3 Floor Polygon" = POLYGON
V1 = ( 0, 0 )
V2 = ( 0, 14 )
V3 = ( -15.23, 14 )
V4 = ( -15.23, 0 )
..
"EL4 Floor Polygon" = POLYGON
V1 = ( 0, 0 )
V2 = ( 0, 14 )
V3 = ( -15.23, 14 )
V4 = ( -15.23, 0 )
..
"EL5 Floor Polygon" = POLYGON
V1 = ( 0, 0 )
V2 = ( 0, 45.7 )
V3 = ( -30.46, 45.7 )
V4 = ( -30.46, 0 )
..
"EL5 Roof Polygon 1" = POLYGON
V1 = ( 2, -2 )
V2 = ( 2, 47.7 )
V3 = ( -32.46, 47.7 )
V4 = ( -32.46, -2 )
..
"EL5 Roof Polygon 1 Wall 1" = POLYGON
V1 = ( 0, 0 )
V2 = ( 45.7, 0 )
V3 = ( 45.7, 30.46 )
V4 = ( 0, 30.46 )
..
"EL5 Roof Polygon 2" = POLYGON
V1 = ( 2, -2 )
V2 = ( 2, 47.7 )
V3 = ( -32.46, 47.7 )
V4 = ( -32.46, -2 )
..
"EL5 Roof Polygon 2 Wall 1" = POLYGON
V1 = ( 0, 0 )
V2 = ( 49.7, 0 )
V3 = ( 49.7, 19.01 )
V4 = ( 0, 19.01 )
..
"EL5 Roof Polygon 2 Wall 2" = POLYGON
132
V1 = ( 0, 0 )
V2 = ( 45.7, 0 )
V3 = ( 45.7, 2 )
V4 = ( 0, 2 )
..
"EL5 Roof Polygon 2 Wall 3" = POLYGON
V1 = ( 0, 0 )
V2 = ( 34.46, 0 )
V3 = ( 17.23, 8.04 )
..
"EL5 Roof Polygon 2 Wall 4" = POLYGON
V1 = ( 0, 0 )
V2 = ( 49.7, 0 )
V3 = ( 49.7, 19.01 )
V4 = ( 0, 19.01 )
..
"EL5 Roof Polygon 2 Wall 5" = POLYGON
V1 = ( 0, 0 )
V2 = ( 45.7, 0 )
V3 = ( 45.7, 2 )
V4 = ( 0, 2 )
..
"EL5 Roof Polygon 2 Wall 6" = POLYGON
V1 = ( 0, 0 )
V2 = ( 34.46, 0 )
V3 = ( 17.23, 8.04 )
..
"EL6 Floor Polygon" = POLYGON
V1 = ( 0, 0 )
V2 = ( 0, 14 )
V3 = ( -15.23, 14 )
V4 = ( -15.23, 0 )
..
"EL7 Floor Polygon" = POLYGON
V1 = ( 0, 0 )
V2 = ( 0, 14 )
V3 = ( 0, 36.85 )
V4 = ( 0, 59.7 )
V5 = ( -15.23, 59.7 )
V6 = ( -15.23, 73.7 )
V7 = ( -30.46, 73.7 )
V8 = ( -30.46, 59.7 )
V9 = ( -30.46, 36.85 )
V10 = ( -30.46, 14 )
V11 = ( -15.23, 14 )
V12 = ( -15.23, 0 )
..
"EL7 Space Polygon 1" = POLYGON
V1 = ( 0, 0 )
V2 = ( 22.85, 0 )
V3 = ( 22.85, 30.46 )
V4 = ( 0, 30.46 )
V5 = ( 0, 15.23 )
..
"EL7 Space Polygon 2" = POLYGON
V1 = ( 0, 0 )
V2 = ( 22.85, 0 )
V3 = ( 22.85, 15.23 )
V4 = ( 22.85, 30.46 )
V5 = ( 0, 30.46 )
..
"EL7 Space Polygon 3" = POLYGON
133
V1 = ( 0, 0 )
V2 = ( 14, 0 )
V3 = ( 14, 15.23 )
V4 = ( 0, 15.23 )
..
"EL7 Space Polygon 4" = POLYGON
V1 = ( 0, 0 )
V2 = ( 14, 0 )
V3 = ( 14, 15.23 )
V4 = ( 0, 15.23 )
..
"EL7 Roof Polygon 1" = POLYGON
V1 = ( 2, -2 )
V2 = ( 2, 61.7 )
V3 = ( -13.23, 61.7 )
V4 = ( -13.23, 75.7 )
V5 = ( -32.46, 75.7 )
V6 = ( -32.46, 12 )
V7 = ( -17.23, 12 )
V8 = ( -17.23, -2 )
..
"EL7 Roof Polygon 1 Wall 1" = POLYGON
V1 = ( 0, 0 )
V2 = ( 14, 0 )
V3 = ( 36.85, 0 )
V4 = ( 59.7, 0 )
V5 = ( 59.7, 15.23 )
V6 = ( 73.7, 15.23 )
V7 = ( 73.7, 30.46 )
V8 = ( 59.7, 30.46 )
V9 = ( 36.85, 30.46 )
V10 = ( 14, 30.46 )
V11 = ( 14, 15.23 )
V12 = ( 0, 15.23 )
..
"EL7 Roof Polygon 2" = POLYGON
V1 = ( 2, -2 )
V2 = ( 2, 61.7 )
V3 = ( -13.23, 61.7 )
V4 = ( -13.23, 75.7 )
V5 = ( -32.46, 75.7 )
V6 = ( -32.46, 12 )
V7 = ( -17.23, 12 )
V8 = ( -17.23, -2 )
..
"EL7 Roof Polygon 2 Wall 1" = POLYGON
V1 = ( 0, 0 )
V2 = ( 63.7, 0 )
V3 = ( 46.46, 19.01 )
V4 = ( 31.23, 19.01 )
V5 = ( 23.62, 10.61 )
V6 = ( 0, 10.61 )
..
"EL7 Roof Polygon 2 Wall 2" = POLYGON
V1 = ( 0, 0 )
V2 = ( 59.7, 0 )
V3 = ( 61.7, 2 )
V4 = ( 0, 2 )
..
"EL7 Roof Polygon 2 Wall 3" = POLYGON
V1 = ( 0, 0 )
V2 = ( 15.23, 0 )
134
V3 = ( 24.85, 10.61 )
V4 = ( 17.23, 19.01 )
..
"EL7 Roof Polygon 2 Wall 4" = POLYGON
V1 = ( 0, 0 )
V2 = ( 15.23, 0 )
V3 = ( 13.23, 2 )
V4 = ( -2, 2 )
..
"EL7 Roof Polygon 2 Wall 5" = POLYGON
V1 = ( 0, 0 )
V2 = ( 14, 0 )
V3 = ( 14, 10.61 )
V4 = ( -9.62, 10.61 )
..
"EL7 Roof Polygon 2 Wall 6" = POLYGON
V1 = ( 0, 0 )
V2 = ( 14, 0 )
V3 = ( 14, 2 )
V4 = ( 2, 2 )
..
"EL7 Roof Polygon 2 Wall 7" = POLYGON
V1 = ( 0, 0 )
V2 = ( 19.23, 0 )
V3 = ( 9.62, 4.48 )
..
"EL7 Roof Polygon 2 Wall 8" = POLYGON
V1 = ( 0, 0 )
V2 = ( 63.7, 0 )
V3 = ( 46.46, 19.01 )
V4 = ( 31.23, 19.01 )
V5 = ( 23.62, 10.61 )
V6 = ( 0, 10.61 )
..
"EL7 Roof Polygon 2 Wall 9" = POLYGON
V1 = ( 0, 0 )
V2 = ( 59.7, 0 )
V3 = ( 61.7, 2 )
V4 = ( 0, 2 )
..
"EL7 Roof Polygon 2 Wall 10" = POLYGON
V1 = ( 0, 0 )
V2 = ( 15.23, 0 )
V3 = ( 24.85, 10.61 )
V4 = ( 17.23, 19.01 )
..
"EL7 Roof Polygon 2 Wall 11" = POLYGON
V1 = ( 0, 0 )
V2 = ( 15.23, 0 )
V3 = ( 13.23, 2 )
V4 = ( -2, 2 )
..
"EL7 Roof Polygon 2 Wall 12" = POLYGON
V1 = ( 0, 0 )
V2 = ( 14, 0 )
V3 = ( 14, 10.61 )
V4 = ( -9.62, 10.61 )
..
"EL7 Roof Polygon 2 Wall 13" = POLYGON
V1 = ( 0, 0 )
V2 = ( 14, 0 )
V3 = ( 14, 2 )
135
V4 = ( 2, 2 )
..
"EL7 Roof Polygon 2 Wall 14" = POLYGON
V1 = ( 0, 0 )
V2 = ( 19.23, 0 )
V3 = ( 9.62, 4.48 )
..
"EL8 Floor Polygon" = POLYGON
V1 = ( 0, 0 )
V2 = ( 0, 14 )
V3 = ( 0, 36.85 )
V4 = ( 0, 59.7 )
V5 = ( -15.23, 59.7 )
V6 = ( -15.23, 73.7 )
V7 = ( -30.46, 73.7 )
V8 = ( -30.46, 59.7 )
V9 = ( -30.46, 36.85 )
V10 = ( -30.46, 14 )
V11 = ( -15.23, 14 )
V12 = ( -15.23, 0 )
..
"EL8 Space Polygon 1" = POLYGON
V1 = ( 0, 0 )
V2 = ( 22.85, 0 )
V3 = ( 22.85, 30.46 )
V4 = ( 0, 30.46 )
V5 = ( 0, 15.23 )
..
"EL8 Space Polygon 2" = POLYGON
V1 = ( 0, 0 )
V2 = ( 22.85, 0 )
V3 = ( 22.85, 15.23 )
V4 = ( 22.85, 30.46 )
V5 = ( 0, 30.46 )
..
"EL8 Space Polygon 3" = POLYGON
V1 = ( 0, 0 )
V2 = ( 14, 0 )
V3 = ( 14, 15.23 )
V4 = ( 0, 15.23 )
..
"EL8 Space Polygon 4" = POLYGON
V1 = ( 0, 0 )
V2 = ( 14, 0 )
V3 = ( 14, 15.23 )
V4 = ( 0, 15.23 )
..
"EL8 Roof Polygon 1" = POLYGON
V1 = ( 2, -2 )
V2 = ( 2, 61.7 )
V3 = ( -13.23, 61.7 )
V4 = ( -13.23, 75.7 )
V5 = ( -32.46, 75.7 )
V6 = ( -32.46, 12 )
V7 = ( -17.23, 12 )
V8 = ( -17.23, -2 )
..
"EL8 Roof Polygon 1 Wall 1" = POLYGON
V1 = ( 0, 0 )
V2 = ( 14, 0 )
V3 = ( 36.85, 0 )
V4 = ( 59.7, 0 )
136
V5 = ( 59.7, 15.23 )
V6 = ( 73.7, 15.23 )
V7 = ( 73.7, 30.46 )
V8 = ( 59.7, 30.46 )
V9 = ( 36.85, 30.46 )
V10 = ( 14, 30.46 )
V11 = ( 14, 15.23 )
V12 = ( 0, 15.23 )
..
"EL8 Roof Polygon 2" = POLYGON
V1 = ( 2, -2 )
V2 = ( 2, 61.7 )
V3 = ( -13.23, 61.7 )
V4 = ( -13.23, 75.7 )
V5 = ( -32.46, 75.7 )
V6 = ( -32.46, 12 )
V7 = ( -17.23, 12 )
V8 = ( -17.23, -2 )
..
"EL8 Roof Polygon 2 Wall 1" = POLYGON
V1 = ( 0, 0 )
V2 = ( 63.7, 0 )
V3 = ( 46.46, 19.01 )
V4 = ( 31.23, 19.01 )
V5 = ( 23.62, 10.61 )
V6 = ( 0, 10.61 )
..
"EL8 Roof Polygon 2 Wall 2" = POLYGON
V1 = ( 0, 0 )
V2 = ( 59.7, 0 )
V3 = ( 61.7, 2 )
V4 = ( 0, 2 )
..
"EL8 Roof Polygon 2 Wall 3" = POLYGON
V1 = ( 0, 0 )
V2 = ( 15.23, 0 )
V3 = ( 24.85, 10.61 )
V4 = ( 17.23, 19.01 )
..
"EL8 Roof Polygon 2 Wall 4" = POLYGON
V1 = ( 0, 0 )
V2 = ( 15.23, 0 )
V3 = ( 13.23, 2 )
V4 = ( -2, 2 )
..
"EL8 Roof Polygon 2 Wall 5" = POLYGON
V1 = ( 0, 0 )
V2 = ( 14, 0 )
V3 = ( 14, 10.61 )
V4 = ( -9.62, 10.61 )
..
"EL8 Roof Polygon 2 Wall 6" = POLYGON
V1 = ( 0, 0 )
V2 = ( 14, 0 )
V3 = ( 14, 2 )
V4 = ( 2, 2 )
..
"EL8 Roof Polygon 2 Wall 7" = POLYGON
V1 = ( 0, 0 )
V2 = ( 19.23, 0 )
V3 = ( 9.62, 4.48 )
..
137
"EL8 Roof Polygon 2 Wall 8" = POLYGON
V1 = ( 0, 0 )
V2 = ( 63.7, 0 )
V3 = ( 46.46, 19.01 )
V4 = ( 31.23, 19.01 )
V5 = ( 23.62, 10.61 )
V6 = ( 0, 10.61 )
..
"EL8 Roof Polygon 2 Wall 9" = POLYGON
V1 = ( 0, 0 )
V2 = ( 59.7, 0 )
V3 = ( 61.7, 2 )
V4 = ( 0, 2 )
..
"EL8 Roof Polygon 2 Wall 10" = POLYGON
V1 = ( 0, 0 )
V2 = ( 15.23, 0 )
V3 = ( 24.85, 10.61 )
V4 = ( 17.23, 19.01 )
..
"EL8 Roof Polygon 2 Wall 11" = POLYGON
V1 = ( 0, 0 )
V2 = ( 15.23, 0 )
V3 = ( 13.23, 2 )
V4 = ( -2, 2 )
..
"EL8 Roof Polygon 2 Wall 12" = POLYGON
V1 = ( 0, 0 )
V2 = ( 14, 0 )
V3 = ( 14, 10.61 )
V4 = ( -9.62, 10.61 )
..
"EL8 Roof Polygon 2 Wall 13" = POLYGON
V1 = ( 0, 0 )
V2 = ( 14, 0 )
V3 = ( 14, 2 )
V4 = ( 2, 2 )
..
"EL8 Roof Polygon 2 Wall 14" = POLYGON
V1 = ( 0, 0 )
V2 = ( 19.23, 0 )
V3 = ( 9.62, 4.48 )
..
"EL1 Floor Polygon - Mirror" = POLYGON
V1 = ( 0, 0 )
V2 = ( 0, -15.23 )
V3 = ( 14, -15.23 )
V4 = ( 14, 0 )
..
"EL2 Floor Polygon - Mirror" = POLYGON
V1 = ( 0, 0 )
V2 = ( 0, -30.46 )
V3 = ( 45.7, -30.46 )
V4 = ( 45.7, 0 )
..
"EL7 Space Polygon 1 - Mirror" = POLYGON
V1 = ( 0, 0 )
V2 = ( 15.23, 0 )
V3 = ( 30.46, 0 )
V4 = ( 30.46, 22.85 )
V5 = ( 0, 22.85 )
..
138
"EL7 Space Polygon 2 - Mirror" = POLYGON
V1 = ( 0, 0 )
V2 = ( 30.46, 0 )
V3 = ( 30.46, 22.85 )
V4 = ( 15.23, 22.85 )
V5 = ( 0, 22.85 )
..
"EL7 Space Polygon 3 - Mirror" = POLYGON
V1 = ( 0, 0 )
V2 = ( 15.23, 0 )
V3 = ( 15.23, 14 )
V4 = ( 0, 14 )
..

$ ---------------------------------------------------------
$ Wall Parameters
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Fixed and Building Shades
$ ---------------------------------------------------------

"2 Story PV" = BUILDING-SHADE
X = 80
Y = 100
Z = 19.2
HEIGHT = 10.3
WIDTH = 75
AZIMUTH = 180
TILT = 25
..

$ ---------------------------------------------------------
$ Misc Cost Related Objects
$ ---------------------------------------------------------

"Baseline Data" = BASELINE
DISCOUNT-RATE = 6
..

$ *********************************************************
$ ** **
$ ** Floors / Spaces / Walls / Windows / Doors **
$ ** **
$ *********************************************************

"EL4 Ground Flr" = FLOOR
X = 53.2323
Y = 210.394
AZIMUTH = 90
POLYGON = "EL4 Floor Polygon"
SHAPE = POLYGON
FLOOR-HEIGHT = 8.5
SPACE-HEIGHT = 8.5
139
C-DIAGRAM-DATA = *SFAM1-2 Garage1 Diag Data*
..
"EL4 Spc (G.1)" = SPACE
SHAPE = POLYGON
ZONE-TYPE = UNCONDITIONED
PEOPLE-SCHEDULE = "EL1 Occ-1 Sch"
LIGHTING-SCHEDUL = ( "Lighting - Annual" )
LIGHTING-TYPE = ( INCAND )
INF-METHOD = AIR-CHANGE
INF-FLOW/AREA = 0.2125
PEOPLE-HG-LAT = 140
PEOPLE-HG-SENS = 210
LIGHTING-KW = ( 0.048 )
AREA/PERSON = 10000
POLYGON = "EL4 Floor Polygon"
C-SUB-SRC-BTUH = ( 0, 0, 0 )
C-SUB-SRC-KW = ( 0, 0, 0 )
C-ACTIVITY-DESC = *Residential (Garage)*
..
"EL4 South Wall (G.1.E1)" = EXTERIOR-WALL
CONSTRUCTION = "EL4 EWall Construction"
LOCATION = SPACE-V1
SHADING-SURFACE = YES
..
"EL4 North Wall (G.1.E2)" = EXTERIOR-WALL
CONSTRUCTION = "EL4 EWall Construction"
LOCATION = SPACE-V3
SHADING-SURFACE = YES
..
"EL4 North Door (G.1.E2.D1)" = DOOR
CONSTRUCTION = "Sgl Lyr Unins Mtl Door"
X = 1
HEIGHT = 7.5
WIDTH = 12
..
"EL4 West Wall (G.1.E3)" = EXTERIOR-WALL
CONSTRUCTION = "EL4 EWall Construction"
LOCATION = SPACE-V4
SHADING-SURFACE = YES
..
"EL4 Roof (G.1.E4)" = EXTERIOR-WALL
CONSTRUCTION = "EL4 Roof Construction"
LOCATION = TOP
SHADING-SURFACE = YES
..
"EL4 Flr (G.1.U1)" = UNDERGROUND-WALL
CONSTRUCTION = "EL4 UFCons (G.1.U2)"
LOCATION = BOTTOM
..
"EL5 Ground Flr" = FLOOR
X = 67.2323
Y = 210.394
AZIMUTH = 90
POLYGON = "EL5 Floor Polygon"
SHAPE = POLYGON
FLOOR-HEIGHT = 8.5
SPACE-HEIGHT = 8.5
C-DIAGRAM-DATA = *SFAM1-2 Dwelling Diag Data*
..
"EL5 Spc (G.1)" = SPACE
SHAPE = POLYGON
ZONE-TYPE = CONDITIONED
140
PEOPLE-SCHEDULE = "EL2 Occ-2 Sch"
LIGHTING-SCHEDUL = ( "Lighting - Annual", "Lighting - Annual" )
EQUIP-SCHEDULE = ( "EL2 Msc-2 Sch" )
LIGHTING-TYPE = ( &D, INCAND )
INF-METHOD = AIR-CHANGE
INF-FLOW/AREA = 0.0495833
PEOPLE-HG-LAT = 140
PEOPLE-HG-SENS = 210
LIGHTING-KW = ( 0.117, 0.457 )
EQUIP-LATENT = ( 0.1 )
EQUIP-SENSIBLE = ( 0.8 )
EQUIPMENT-W/AREA = ( 0.485 )
AREA/PERSON = 348.036
POLYGON = "EL5 Floor Polygon"
C-SUB-SRC-BTUH = ( 0, 0, 0 )
C-SUB-SRC-KW = ( 0, 0, 0 )
C-ACTIVITY-DESC = *Residential (Living)*
..
"EL5 South Wall (G.1.E1)" = EXTERIOR-WALL
CONSTRUCTION = "EL5 EWall Construction"
LOCATION = SPACE-V1
SHADING-SURFACE = YES
..
"EL5 South Win (G.1.E1.W1)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 1.30924
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 South Win (G.1.E1.W2)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 7.02136
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 South Win (G.1.E1.W3)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 12.7335
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 South Win (G.1.E1.W4)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 18.4456
Y = 3.5
141
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 South Win (G.1.E1.W5)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 24.1577
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 South Win (G.1.E1.W6)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 29.8699
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 South Win (G.1.E1.W7)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 35.582
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 South Win (G.1.E1.W8)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 41.2941
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 East Wall (G.1.E2)" = EXTERIOR-WALL
CONSTRUCTION = "EL5 EWall Construction"
WIDTH = 15.2323
LOCATION = SPACE-V2
SHADING-SURFACE = YES
..
"EL5 East Win (G.1.E2.W1)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 3
Y = 3.5
HEIGHT = 4
142
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
..
"EL5 East Door (G.1.E2.D1)" = DOOR
CONSTRUCTION = "Other Wd Door"
X = 8
HEIGHT = 6.7
WIDTH = 3
..
"EL5 North Wall (G.1.E3)" = EXTERIOR-WALL
CONSTRUCTION = "EL5 EWall Construction"
LOCATION = SPACE-V3
SHADING-SURFACE = YES
..
"EL5 North Win (G.1.E3.W1)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 1.30924
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 North Win (G.1.E3.W2)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 7.02136
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 North Win (G.1.E3.W3)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 12.7335
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 North Win (G.1.E3.W4)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 18.4456
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 North Win (G.1.E3.W5)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
143
X = 24.1577
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 North Win (G.1.E3.W6)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 29.8699
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 North Win (G.1.E3.W7)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 35.582
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 North Win (G.1.E3.W8)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 41.2941
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 West Wall (G.1.E4)" = EXTERIOR-WALL
CONSTRUCTION = "EL5 EWall Construction"
WIDTH = 15.2323
LOCATION = SPACE-V4
SHADING-SURFACE = YES
..
"EL5 West Win (G.1.E4.W1)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 3
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
..
"EL5 West Door (G.1.E4.D1)" = DOOR
CONSTRUCTION = "Other Wd Door"
X = 8
HEIGHT = 6.7
WIDTH = 3
..
144
"EL5 West Wall (G.1.I1)" = INTERIOR-WALL
NEXT-TO = "EL4 Spc (G.1)"
CONSTRUCTION = "Garage Int Wall"
X = -15.2323
Y = 0
Z = 0
HEIGHT = 8.5
WIDTH = 15.2323
AZIMUTH = 180
..
"EL5 Flr (G.1.U1)" = UNDERGROUND-WALL
CONSTRUCTION = "EL5 UFCons (G.1.U2)"
LOCATION = BOTTOM
..
"EL5 Top Flr" = FLOOR
X = 67.2323
Y = 210.394
Z = 8.5
AZIMUTH = 90
POLYGON = "EL5 Floor Polygon"
SHAPE = POLYGON
FLOOR-HEIGHT = 8.5
SPACE-HEIGHT = 8.5
C-DIAGRAM-DATA = *SFAM1-2 Dwelling Diag Data*
..
"EL5 Spc (T.2)" = SPACE
SHAPE = POLYGON
ZONE-TYPE = CONDITIONED
PEOPLE-SCHEDULE = "EL2 Occ-1 Sch"
LIGHTING-SCHEDUL = ( "Lighting - Annual" )
EQUIP-SCHEDULE = ( "EL2 Msc-2 Sch" )
LIGHTING-TYPE = ( INCAND )
INF-METHOD = AIR-CHANGE
INF-FLOW/AREA = 0.0495833
PEOPLE-HG-LAT = 140
PEOPLE-HG-SENS = 210
LIGHTING-KW = ( 1.212 )
EQUIP-LATENT = ( 0.1 )
EQUIP-SENSIBLE = ( 0.8 )
EQUIPMENT-W/AREA = ( 0.323 )
AREA/PERSON = 348.036
POLYGON = "EL5 Floor Polygon"
C-SUB-SRC-BTUH = ( 0, 0, 0 )
C-SUB-SRC-KW = ( 0, 0, 0 )
C-ACTIVITY-DESC = *Residential (Bedroom)*
..
"EL5 South Wall (T.2.E5)" = EXTERIOR-WALL
CONSTRUCTION = "EL5 EWall Construction"
LOCATION = SPACE-V1
SHADING-SURFACE = YES
..
"EL5 South Win (T.2.E5.W1)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 1.30924
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
145
"EL5 South Win (T.2.E5.W2)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 7.02136
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 South Win (T.2.E5.W3)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 12.7335
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 South Win (T.2.E5.W4)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 18.4456
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 South Win (T.2.E5.W5)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 24.1577
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 South Win (T.2.E5.W6)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 29.8699
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 South Win (T.2.E5.W7)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 35.582
Y = 3.5
HEIGHT = 4
146
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 South Win (T.2.E5.W8)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 41.2941
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 East Wall (T.2.E6)" = EXTERIOR-WALL
CONSTRUCTION = "EL5 EWall Construction"
LOCATION = SPACE-V2
SHADING-SURFACE = YES
..
"EL5 East Win (T.2.E6.W1)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 3
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
..
"EL5 North Wall (T.2.E7)" = EXTERIOR-WALL
CONSTRUCTION = "EL5 EWall Construction"
LOCATION = SPACE-V3
SHADING-SURFACE = YES
..
"EL5 North Win (T.2.E7.W1)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 1.30924
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 North Win (T.2.E7.W2)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 7.02136
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 North Win (T.2.E7.W3)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 12.7335
147
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 North Win (T.2.E7.W4)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 18.4456
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 North Win (T.2.E7.W5)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 24.1577
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 North Win (T.2.E7.W6)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 29.8699
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 North Win (T.2.E7.W7)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 35.582
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 North Win (T.2.E7.W8)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 41.2941
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
FRAME-CONDUCT = 4.09
..
"EL5 West Wall (T.2.E8)" = EXTERIOR-WALL
148
CONSTRUCTION = "EL5 EWall Construction"
LOCATION = SPACE-V4
SHADING-SURFACE = YES
..
"EL5 West Win (T.2.E8.W1)" = WINDOW
GLASS-TYPE = "EL5 Window Type #1 GT"
SHADING-SCHEDULE = "DEER Res ShadeSch"
FRAME-WIDTH = 0
X = 3
Y = 3.5
HEIGHT = 4
WIDTH = 3.09365
WIN-SHADE-TYPE = FIXED-INTERIOR
..
"EL5 Flr (T.2.I2)" = INTERIOR-WALL
NEXT-TO = "EL5 Spc (G.1)"
CONSTRUCTION = "EL5 IFlr Construction"
LOCATION = BOTTOM
..
"EL5 UnderRf (T.2.I3)" = INTERIOR-WALL
NEXT-TO = "EL5 Under Roof (T.3)"
CONSTRUCTION = "EL5 AFlr Construction"
LOCATION = TOP
..
"EL5 Under Roof (T.3)" = SPACE
X = 0
Y = 0
Z = 8.5
AZIMUTH = 0
HEIGHT = 8.03557
VOLUME = 6327.73
SHAPE = POLYGON
ZONE-TYPE = UNCONDITIONED
INF-METHOD = RESIDENTIAL
RES-INF-CST = 0
RES-INF-WND = 0.3
RES-INF-TEMP = 0.5
POLYGON = "EL5 Roof Polygon 2"
LOCATION = FLOOR-V1
..
"EL5 Roof (T.3.E9)" = EXTERIOR-WALL
CONSTRUCTION = "EL5 Roof Construction"
X = 2
Y = -2
Z = 0
AZIMUTH = 90
TILT = 25
POLYGON = "EL5 Roof Polygon 2 Wall 1"
SHADING-SURFACE = YES
..
"EL5 Soffet (T.3.E10)" = EXTERIOR-WALL
CONSTRUCTION = "EL5 EWall Construction"
X = 0
Y = 0
Z = 0
AZIMUTH = 90
TILT = 180
POLYGON = "EL5 Roof Polygon 2 Wall 2"
..
"EL5 Gable (T.3.E11)" = EXTERIOR-WALL
CONSTRUCTION = "EL5 EWall Construction"
X = 2
149
Y = 45.697
Z = 0
AZIMUTH = 0
TILT = 90
POLYGON = "EL5 Roof Polygon 2 Wall 3"
SHADING-SURFACE = YES
..
"EL5 Roof (T.3.E12)" = EXTERIOR-WALL
CONSTRUCTION = "EL5 Roof Construction"
X = -32.4647
Y = 47.697
Z = 0
AZIMUTH = -90
TILT = 25
POLYGON = "EL5 Roof Polygon 2 Wall 4"
SHADING-SURFACE = YES
..
"EL5 Soffet (T.3.E13)" = EXTERIOR-WALL
CONSTRUCTION = "EL5 EWall Construction"
X = -30.4647
Y = 45.697
Z = 0
AZIMUTH = -90
TILT = 180
POLYGON = "EL5 Roof Polygon 2 Wall 5"
..
"EL5 Gable (T.3.E14)" = EXTERIOR-WALL
CONSTRUCTION = "EL5 EWall Construction"
X = -32.4647
Y = 0
Z = 0
AZIMUTH = 180
TILT = 90
POLYGON = "EL5 Roof Polygon 2 Wall 6"
SHADING-SURFACE = YES
..
"EL6 Ground Flr" = FLOOR
X = 112.929
Y = 225.626
AZIMUTH = 90
POLYGON = "EL6 Floor Polygon"
SHAPE = POLYGON
FLOOR-HEIGHT = 8.5
SPACE-HEIGHT = 8.5
C-DIAGRAM-DATA = *SFAM1-2 Garage2 Diag Data*
..
"EL6 Spc (G.1)" = SPACE
SHAPE = POLYGON
ZONE-TYPE = UNCONDITIONED
PEOPLE-SCHEDULE = "EL1 Occ-1 Sch"
LIGHTING-SCHEDUL = ( "Lighting - Annual" )
LIGHTING-TYPE = ( INCAND )
INF-METHOD = AIR-CHANGE
INF-FLOW/AREA = 0.2125
PEOPLE-HG-LAT = 140
PEOPLE-HG-SENS = 210
LIGHTING-KW = ( 0.048 )
AREA/PERSON = 10000
POLYGON = "EL6 Floor Polygon"
C-SUB-SRC-BTUH = ( 0, 0, 0 )
C-SUB-SRC-KW = ( 0, 0, 0 )
C-ACTIVITY-DESC = *Residential (Garage)*
150
..
"EL6 South Wall (G.1.E1)" = EXTERIOR-WALL
CONSTRUCTION = "EL6 EWall Construction"
LOCATION = SPACE-V1
SHADING-SURFACE = YES
..
"EL6 South Door (G.1.E1.D1)" = DOOR
CONSTRUCTION = "Sgl Lyr Unins Mtl Door"
X = 1
HEIGHT = 7.5
WIDTH = 12
..
"EL6 East Wall (G.1.E2)" = EXTERIOR-WALL
CONSTRUCTION = "EL6 EWall Construction"
LOCATION = SPACE-V2
SHADING-SURFACE = YES
..
"EL6 North Wall (G.1.E3)" = EXTERIOR-WALL
CONSTRUCTION = "EL6 EWall Construction"
LOCATION = SPACE-V3
SHADING-SURFACE = YES
..
"EL6 Roof (G.1.E4)" = EXTERIOR-WALL
CONSTRUCTION = "EL6 Roof Construction"
LOCATION = TOP
SHADING-SURFACE = YES
..
"EL6 West Wall (G.1.I1)" = INTERIOR-WALL
NEXT-TO = "EL5 Spc (G.1)"
CONSTRUCTION = "Garage Int Wall"
X = -15.2323
Y = 0
Z = 0
HEIGHT = 8.5
WIDTH = 15.2323
AZIMUTH = 180
..
"EL6 Flr (G.1.U1)" = UNDERGROUND-WALL
CONSTRUCTION = "EL6 UFCons (G.1.U2)"
LOCATION = BOTTOM
..

$ *********************************************************
$ ** **
$ ** Performance Curves **
$ ** **
$ *********************************************************

"SA-13-ML - Cool Cap f(T)" = CURVE-FIT
TYPE = BI-QUADRATIC-T
INPUT-TYPE = COEFFICIENTS
COEFFICIENTS = ( 1.191, -0.01965, 0.0003156, 0.003059, -9.333e-006,
-7.825e-005 )
..
"SA-13-ML - Sens Cap f(T)" = CURVE-FIT
TYPE = BI-QUADRATIC-T
INPUT-TYPE = COEFFICIENTS
COEFFICIENTS = ( 2.921, -0.001002, -0.0003273, -0.006823, 1.642e-005,
1.812e-005 )
..
"SA-13-ML - EIR f(T)" = CURVE-FIT
151
TYPE = BI-QUADRATIC-T
INPUT-TYPE = COEFFICIENTS
COEFFICIENTS = ( -0.06819, 0.02228, -0.0001172, 0.001059, 0.0001482,
-0.00021 )
..
"SA-13-ML - Coil BF f(T)" = CURVE-FIT
TYPE = BI-QUADRATIC-T
INPUT-TYPE = COEFFICIENTS
COEFFICIENTS = ( -40, 0.3104, 0.001279, 0.7628, -0.001995, -0.006306 )
..
"SA-13-ML - EIR f(PLR)" = CURVE-FIT
TYPE = CUBIC
INPUT-TYPE = COEFFICIENTS
COEFFICIENTS = ( 5.291e-006, 1.089, -0.1027, 0.01356 )
..
"SA-13-ML - C-Loss f(PLR)" = CURVE-FIT
TYPE = QUADRATIC
INPUT-TYPE = COEFFICIENTS
COEFFICIENTS = ( 0.9176, 0.08897, -0.006616 )
..
"SA-13-ML - BF f(Flow)" = CURVE-FIT
TYPE = LINEAR
INPUT-TYPE = COEFFICIENTS
OUTPUT-MIN = 0
OUTPUT-MAX = 1
COEFFICIENTS = ( 1, 0 )
..

$ *********************************************************
$ ** **
$ ** Electric & Fuel Meters **
$ ** **
$ *********************************************************

$ ---------------------------------------------------------
$ Electric Meters
$ ---------------------------------------------------------

"EM1" = ELEC-METER
TYPE = UTILITY
COGEN-TRACK-MODE = MAX-OUTPUT
..
"House 3" = ELEC-METER
TYPE = UTILITY
COGEN-TRACK-MODE = MAX-OUTPUT
..
"House 4" = ELEC-METER
TYPE = UTILITY
COGEN-TRACK-MODE = MAX-OUTPUT
..

$ ---------------------------------------------------------
$ Fuel Meters
$ ---------------------------------------------------------

"FM2" = FUEL-METER
TYPE = NATURAL-GAS
..

152
$ ---------------------------------------------------------
$ Master Meters
$ ---------------------------------------------------------

"MASTER-METERS 1" = MASTER-METERS
MSTR-ELEC-METER = "EM1"
MSTR-FUEL-METER = "FM1"
..

$ *********************************************************
$ ** **
$ ** HVAC Circulation Loops / Plant Equipment **
$ ** **
$ *********************************************************

$ ---------------------------------------------------------
$ Pumps
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Heat Exchangers
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Circulation Loops
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Chillers
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Boilers
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Domestic Water Heaters
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Heat Rejection
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Tower Free Cooling
$ ---------------------------------------------------------

153

$ ---------------------------------------------------------
$ Photovoltaic Modules
$ ---------------------------------------------------------

"Sunpower SPR-220" = PV-MODULE
TYPE = MC-SI
HEIGHT = 5.116
WIDTH = 2.62
VOLTS-OPEN-CKT = 48.3
VOLTS/T-OPEN-CKT = -0.1368
AMPS-SHORT-CKT = 5.95
AMPS/T-SHORT-CKT = 0.000387
VOLTS-MAX-PWR = 39.8
AMPS-MAX-PWR = 5.53
..

$ ---------------------------------------------------------
$ Electric Generators
$ ---------------------------------------------------------

"2-Story House -Sunny Boy SB1100U" = ELEC-GENERATOR
TYPE = PV-ARRAY
CAPACITY = 4
ELEC-METER = "House 3"
NUM-INVERTERS = 1
MIN-OPER-VOLTS = 220
MIN-TRACK-VOLTS = 250
MAX-TRACK-VOLTS = 480
PV-MODULE = "Sunpower SPR-220"
MODULES-SERIES = 11
MODULES-PARALLEL = 2
MOUNT-TYPE = BUILDING-SHADE
BUILDING-SHADE = "2 Story PV"
..

$ ---------------------------------------------------------
$ Thermal Storage
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Ground Loop Heat Exchangers
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Compliance DHW (residential dwelling units)
$ ---------------------------------------------------------

$ *********************************************************
$ ** **
$ ** Steam & Chilled Water Meters **
$ ** **
$ *********************************************************
154

$ ---------------------------------------------------------
$ Steam Meters
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Chilled Water Meters
$ ---------------------------------------------------------

$ *********************************************************
$ ** **
$ ** HVAC Systems / Zones **
$ ** **
$ *********************************************************

"S3 Sys (PVVT)" = SYSTEM
TYPE = PVVT
HEAT-SOURCE = FURNACE
ZONE-HEAT-SOURCE = NONE
BASEBOARD-SOURCE = NONE
RETURN-UA = 56.8222
MAX-SUPPLY-T = 120
MIN-SUPPLY-T = 40
ECONO-LIMIT-T = 65
ECONO-LOCKOUT = YES
SUPPLY-FLOW = 1433
MIN-OUTSIDE-AIR = 0
OA-CONTROL = FIXED
DUCT-AIR-LOSS = 0.067
VENT-METHOD = AIR-CHANGE
VENT-TEMP-SCH = "DEER Res Nat Vent Temp Sch"
NATURAL-VENT-AC = 3
NATURAL-VENT-SCH = "DEER Res Nat Vent On Sch"
OPEN-VENT-SCH = "DEER Res Nat Vent Open Sch"
DUCT-UA = 99.7229
FAN-SCHEDULE = "S3 Sys3 (PVVT) Fan Sch"
FAN-CONTROL = FAN-EIR-FPLR
SUPPLY-DELTA-T = 1.15024
SUPPLY-KW/FLOW = 0.000364
FAN-PLACEMENT = BLOW-THROUGH
RETURN-EFF = 0.5
FAN-EIR-FPLR = "Residential Fix Vol-Fan EIR"
INDOOR-FAN-MODE = INTERMITTENT
MIN-FLOW-RATIO = 0.9989
HMIN-FLOW-RATIO = 0.9989
COOLING-CAPACITY = 43000
COOL-CAP-FT = "SA-13-ML - Cool Cap f(T)"
COOLING-EIR = 0.2567
COOL-EIR-FT = "SA-13-ML - EIR f(T)"
COOL-EIR-FPLR = "SA-13-ML - EIR f(PLR)"
COOL-SH-FT = "SA-13-ML - Sens Cap f(T)"
COIL-BF = 0.1148
COIL-BF-FFLOW = "SA-13-ML - BF f(Flow)"
COIL-BF-FT = "SA-13-ML - Coil BF f(T)"
COOL-CTRL-RANGE = 0
MIN-UNLOAD-RATIO = 1
MIN-HGB-RATIO = 1
CRANKCASE-HEAT = 0
155
HEATING-CAPACITY = -67579.8
HEAT-CAP-FT = "RESYS-Heat-Cap-fEDB&OAT"
HEAT-EIR-FT = "RESYS-Heat-EIR-fEDB&OAT"
HEAT-EIR-FPLR = "RESYS-Heat-EIR-fPLR"
FURNACE-AUX = 0
FURNACE-HIR = 1.24155
FURNACE-HIR-FPLR = "Furnace-HIR-fPLR"
COIL-BF-FPLR = "RESYS-Bypass-Factor-fPLR"
COOL-CLOSS-FPLR = "SA-13-ML - C-Loss f(PLR)"
HEAT-CLOSS-MIN = 0.01
COOL-CLOSS-MIN = 0.01
DUCT-AIR-LOSS-OA = 0.1
SIZING-OPTION = NON-COINCIDENT
DUCT-ZONE = "EL5 Roof Zone 1"
MSTR-ELEC-METER = "House 4"
MSTR-FUEL-METER = "FM2"
CONTROL-ZONE = "EL5 Zn (T.2)"
AIR/TEMP-CONTROL = TWO-SPEED
COOL-STAGES = ( 0.9989, 1 )
HEAT-STAGES = ( 0.9989, 1 )
..
"EL5 Zn (G.1)" = ZONE
TYPE = CONDITIONED
MIN-FLOW-RATIO = 1
DESIGN-HEAT-T = 72
HEAT-TEMP-SCH = "Buntine Thermostat Heating"
DESIGN-COOL-T = 75
COOL-TEMP-SCH = "Buntine Thermostat Cooling"
SIZING-OPTION = ADJUST-LOADS
SPACE = "EL5 Spc (G.1)"
..
"EL5 Roof Zone 1" = ZONE
TYPE = UNCONDITIONED
DESIGN-HEAT-T = 53
DESIGN-COOL-T = 91
SIZING-OPTION = ADJUST-LOADS
SPACE = "EL5 Under Roof (T.3)"
..
"EL5 Zn (T.2)" = ZONE
TYPE = CONDITIONED
MIN-FLOW-RATIO = 1
DESIGN-HEAT-T = 72
HEAT-TEMP-SCH = "Buntine Thermostat Heating"
DESIGN-COOL-T = 75
COOL-TEMP-SCH = "Buntine Thermostat Cooling"
SIZING-OPTION = ADJUST-LOADS
SPACE = "EL5 Spc (T.2)"
..
"EL4 Zn (G.1)" = ZONE
TYPE = UNCONDITIONED
DESIGN-HEAT-T = 72
DESIGN-COOL-T = 75
SIZING-OPTION = ADJUST-LOADS
SPACE = "EL4 Spc (G.1)"
..
"EL6 Zn (G.1)" = ZONE
TYPE = UNCONDITIONED
DESIGN-HEAT-T = 72
DESIGN-COOL-T = 75
SIZING-OPTION = ADJUST-LOADS
SPACE = "EL6 Spc (G.1)"
..
156

$ *********************************************************
$ ** **
$ ** Metering & Misc HVAC **
$ ** **
$ *********************************************************

$ ---------------------------------------------------------
$ Equipment Controls
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Load Management
$ ---------------------------------------------------------

$ *********************************************************
$ ** **
$ ** Utility Rates **
$ ** **
$ *********************************************************

$ ---------------------------------------------------------
$ Ratchets
$ ---------------------------------------------------------

$ ---------------------------------------------------------
$ Block Charges
$ ---------------------------------------------------------

"Block Charge 1" = BLOCK-CHARGE
BLOCK-SCH = "SCE Winter/Summer Schedule"
SCH-FLAG = 1
BLOCKS-1 = ( 285.6, 85.68, 199.92, 840 )
COSTS-1 = ( 0.13, 0.15, 0.204, 0.27 )
..
"Block Charge 2" = BLOCK-CHARGE
BLOCK-SCH = "SCE Winter/Summer Schedule"
SCH-FLAG = 2
BLOCKS-1 = ( 306, 91.8, 214.2, 900 )
COSTS-1 = ( 0.13, 0.15, 0.204, 0.27 )
..
"Block Charge 3" = BLOCK-CHARGE
BLOCK-SCH = "SCE Winter/Summer Schedule"
SCH-FLAG = 3
BLOCKS-1 = ( 316.2, 94.86, 221.34, 930 )
COSTS-1 = ( 0.13, 0.15, 0.204, 0.27 )
..
"Block Charge 7" = BLOCK-CHARGE
BLOCK-SCH = "TOU Tariff"
SCH-FLAG = 1
BLOCKS-1 = ( 2000 )
COSTS-1 = ( 0.13631 )
..
"Block Charge 8" = BLOCK-CHARGE
BLOCK-SCH = "TOU Tariff"
157
SCH-FLAG = 2
BLOCKS-1 = ( 2000 )
COSTS-1 = ( 0.62498 )
..

$ ---------------------------------------------------------
$ Utility Rates
$ ---------------------------------------------------------

"Domestic D" = UTILITY-RATE
TYPE = ELECTRICITY
ELEC-METERS = ( "House 4" )
MONTH-CHGS = ( 0.9 )
BLOCK-CHARGES = ( "Block Charge 1", "Block Charge 2", "Block Charge 3" )
BUY/SELL-MODE = NET-YEARLY
NET-SALE-CREDITS = ENERGY&DEMAND
..
"TOU Tariff 1" = UTILITY-RATE
TYPE = ELECTRICITY
ELEC-METERS = ( "House 4" )
BLOCK-CHARGES = ( "Block Charge 7", "Block Charge 8" )
..

$ *********************************************************
$ ** **
$ ** Output Reporting **
$ ** **
$ *********************************************************

$ ---------------------------------------------------------
$ Loads Non-Hourly Reporting
$ ---------------------------------------------------------

LOADS-REPORT
VERIFICATION = ( ALL-VERIFICATION )
SUMMARY = ( ALL-SUMMARY )
..

$ ---------------------------------------------------------
$ Systems Non-Hourly Reporting
$ ---------------------------------------------------------

SYSTEMS-REPORT
VERIFICATION = ( ALL-VERIFICATION )
SUMMARY = ( ALL-SUMMARY )
..

$ ---------------------------------------------------------
$ Plant Non-Hourly Reporting
$ ---------------------------------------------------------

PLANT-REPORT
VERIFICATION = ( ALL-VERIFICATION )
SUMMARY = ( ALL-SUMMARY )
..

$ ---------------------------------------------------------
158
$ Economics Non-Hourly Reporting
$ ---------------------------------------------------------

ECONOMICS-REPORT
VERIFICATION = ( ALL-VERIFICATION )
SUMMARY = ( ALL-SUMMARY )
..

$ ---------------------------------------------------------
$ Hourly Reporting
$ ---------------------------------------------------------

"Total Energy Use - 2 story" = REPORT-BLOCK
VARIABLE-TYPE = "House 4"
VARIABLE-LIST = ( 1, 3, 20 )
..
"Hourly Report Block 2" = REPORT-BLOCK
VARIABLE-TYPE = "S3 Sys (PVVT)"
VARIABLE-LIST = ( 210, 47, 49, 45 )
..
"Hourly Report Block 3" = REPORT-BLOCK
VARIABLE-TYPE = "2-Story House -Sunny Boy SB1100U"
VARIABLE-LIST = ( 1 )
..
"Hourly Report Block 4" = REPORT-BLOCK
VARIABLE-TYPE = GLOBAL
VARIABLE-LIST = ( 4, 15, 17, 3 )
..
"loads2" = REPORT-BLOCK
VARIABLE-TYPE = "EL5 Spc (T.2)"
VARIABLE-LIST = ( 16, 17, 18, 19, 20, 21, 22, 23, 24, 25, 26, 27, 33,
36, 42, 37 )
..
"Hourly Report Block 6" = REPORT-BLOCK
VARIABLE-TYPE = GLOBAL
VARIABLE-LIST = ( 6, 14, 13, 15 )
..

"Hourly Report 1" = HOURLY-REPORT
REPORT-SCHEDULE = "DEER Demand Season Sched"
REPORT-BLOCK = ( "Total Energy Use - 2 story", "Hourly Report Block 2",
"Hourly Report Block 3", "Hourly Report Block 4",
"Hourly Report Block 6" )
..
"Hourly Report 2" = HOURLY-REPORT
REPORT-SCHEDULE = "DEER Demand Season Sched"
REPORT-BLOCK = ( "loads2" )
..

$ ---------------------------------------------------------
$ THE END
$ ---------------------------------------------------------

END ..
COMPUTE ..
STOP ..

Abstract (if available)

Abstract Meeting peak electric demand poses a significant challenge to electric utilities in California. The increased use of air conditioning, driven by high summer temperatures, is the primary cause of this peak demand. This thesis evaluated strategies for eliminating peak electric demand in single family residential buildings sited in California climate zone 10. Alternative building designs were analyzed using eQuest to determine the impact of different energy efficiency measures and rooftop photovoltaics on peak demand. The simulation results revealed the hourly peak demand between 2 and 5pm during the hottest three day period contained in the TMY weather data for California climate zone 10. Based on these results it was concluded that zero electric peak demand designs are technically achievable. A life cycle cost analysis indicated that these buildings are not yet cost effective and the net present value is highly sensitive to electricity tariffs and installed photovoltaic system costs. Zero peak demand residential buildings represent a key strategy in the effort to address California's grid congestion and significantly reduce the environmental impacts of peak electrical generation.

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University of Southern California Dissertations and Theses

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