-‘nwWW

ThESIS

 

A METHOD FOR ALLOCATING

EIEC'IRIC POVER C(MPANY PROPERTY VALUES

'1.

Thomas {Dee \ U

“

Thesis for Days a]: E‘ E.
_ 41“.» 3; 5‘...

1934

~ THEsIS

 

INTR ODUCTION

At this time, when electric service rates are of vital
interest in the United States, there is a definite demand for a
method of cost-of-service analysis which will show the relation
between the cost of the service rendered and the charges for such
service, not only for service as a whole but also for each of ttn
various classes of electric service rendered.

Certain state utility regulatory bodies have called an
utilities under their Jurisdiction for cost analyses of this kind
by classes of service or by rate schedules. In some cases it has
been claimed that an accurate analysis of this kind cannot be made,
or, that even if it were possible, the analysis would have very
little permanent value because of the ever-changing conditions of
the relative volume, demand and other characteristics of each of
the various classes of service rendered.

'The author recognizes that an analysis of the cost of
service for a period in the past does not necessarily result in
determining the proper rate to be charged in the future, and that
the analysis cannot determine the effect upon rates of changing
economic, social and industrial conditions which my increase or
decrease the future demands for any certain class of electric
service. Nevertheless, he believes that analyses of this type may
be made of great value in establishing reasonable rates and that
periodic analyses must furnish the guide by which intelligent
management plots its future pathway in regard to rates. Such an
analysis, for example, is invaluable for the study of a proposed
new rate schedule, in the defense of the reasmableness of an
existing rate or in resisting the establishment of an unreasonable
and confiscatory rate.

The method described‘ in this thesis covers only that
part of the analysis which concerns the allocation of property value
against each of the various classes of electric service rendered by
an electric power utility. The method is not new in principle but,
so far as the author has been able to determine by extensive reading
and consultatim, is new in its manner of determining the necessary
factors for such an allocation of property value. Briefly, tb method
outlined in this thesis utilizes comercial and operating data
collected as a matter of routine operation by the majority of large
operating companies and requires little or no special data. To this
extent it is new and outlines a systm whereby the vast expanse of
the usual methods of allocation can be considerably decre seed.

The method described has been utilized recently by a

large utility in determining its property value allocation against
certain classes of service rendered.

9547”?

2.

GENERAL

rectors Involved in Determining Rates

 

A fair rate for any class of electric service must be
based on the cost of supplying that service. In all fairness the
costs incurred on the behalf of one class of customers must be paid
by that class. This involves an allocation of costs incurred against
the various classes of service, a process of intricate detail and
apparently at times impossible. Yet the problem yields to intelligent
attack and the method, while laborious in the extreme, is accurate to
an extent not at first apparent.

The term “cost of service" must include both operating
expense and carrying charges on the value of the electric system.
Operating expense includes the costs of labor and of material’used
in rendering electric service. Labor costs include such itans as
wages paid to linemen, groundmen, substation and power plant operators,
load dispatchers, metermen, troublemen, clerks, stenographers, foremn,
engineers, superintendents, managers and other labor of numerous types.
Material includes coal for the boilers, oil for the turbines, repair
parts for damaged apparatus and so on through a list of thousands of
items. Included in the cost of operation also are my forms of
insurance and taxes, such as fire, automobile and compensation insurance
and income and excise taxes.

Carrying charges on the value of the electric systan include
such items as interest, the rental price or hire of the dollars used in
building the system; depreciation and obsolescence, the provision for
the replacement of the capital invested in the system, which may vanish
from wear or from functional old age of the equipnent; and all those
taxes which are based on the value of‘physical property.

The item of carrying charges on the value of the electric
system is a major factor in arriving at the cost of service. In the
majority of companies it represents from fifty to eighty percent or
more of the cost of service; hence the necessity for an accurate
allocation of the value of property used and useful in rendering
service against the various classes of property which it serves.

01'- importance also are the trends of operating costs and
carrying charges over a period of years. Any allocation is at best
only a tanporary picture of conditions as they then exist; conditions
may have been radically different last year and equally as well may be
radically different next year. For instance, in these depression times
the investment in electric systems is as great as or greater than it
was during the more prosperous period of several years ago. Yet the
load served, both in kilowatts of demand and in total kilowatt hours
sold, is much less than that of 1929, for exmple. Operating labor
can be reduced but slightly with decreasing loads and the same is true
of operating material. Enos, any analysis at a given period must be

viewed to some extent from the standpoint of a long term of years
and the probable future picture, before it can be used in establish-
ing rates. The best guide for planning the future is obviously the
experience of the past; therefore the long term trend of operating
‘costs and carrying charges is tremendously important.

Allocation of Pr0perty Against Classes of Service

 

In any rate case, whether it is the establishment of a
new rate or the defense of an existing rate, the problem is relatively
simple in principle. Briefly, after subtracting operating expenses
from income, the remainder should provide for property taxes, deprecia-
. tion and obsolescence, and a fair rate of return on the value of the
property used and useful in rendering service.

In theory a single simple universal rate applicable to all
classes of electric service would seem to be ideal. Such a rate,
however, would actually be discriminatory and would result in certain
classes of customers obtaining service at (mly part of its actual cost,
the balance of the cost being borne by other classes of customers.

The proper single rate might be evolved, but it would be so complex

as to render its use practically impossible. Hence it is the cannon
practice amongst electric power companies to divide the whole field

of customers into a relatively small number of classes, this division
being based on the character of use of electric service. For each
different class of customr or service there is a rate structure based
on the cost of service to that particular class.

The general divisions or classes of service are essentially
the same for all electric power companies, almost without exception,
though further subdivisions may vary considerably. These general
divisions are residential service, comercial lighting service,
commercial (or retail) power service and industrial (or wholesale) power
service. In addition there may be special classes of service, including
that supplied to electric railways, ice-manufacturing canpanies, electric
welding operations, pipeline pumping canpenies, irrigation projects and
others whose use of electric service varies so far fran the characteristics
of the usual classes that a special rate is necessary.

The residential service class is marked by definite character-
istics, applicable to the vast majority of customers of this class, of
small kilowatt hour consumption per customer, relatively large time
diversity of demand, low load factor, small demand per unit of geographic
area, large investment in electric system per custaner and per kilowatt
of demand, and high cost of service per kilowatt hour. The major use of
residential electric service is for lighting and for small household
appliances, with a relatively mall use for cooking and water heating.

In number of customers, the residential class of service is in the vast
majority and constitutes approximately ninety percent of the custaners
of the usual electric power company.

4.

The next most cormnon class of service is that supplied
to commercial lighting customers. The characteristics of this
class are moderate kilowatt hour consumption per customer, small
time diversity of demand, higher load factor than for residential
service, moderate to large demand per unit of geographic area,
large invesirnent in electric system per customer but moderate on
a per kilowatt of demand basis, and a somewhat lower cost of
service per kilowatt hour than that for residential service. The
predominant use to which this class of service is put is lighting,
with incidental use for small power. This class of customers
usually numbers eight to ten percent of the total for the usual
electric power company.

The commercial poser customers are the next class in
order of number of customers. Small to moderate kilowatt hour
consumption, large time diversity of demand, low load factor, and
usually low cost of service per kilowatt hour are the usual character—
istics of this class of service. The majority of use is for shell
industrial power purposes, with a relatively large preportion of
lighting. This class usually includes only one percent or less of
the total number of customers for the average electric power company.

The industrial power class includes practically all of
the remining custaners, with a few special class custcrners having
special rate structures. This class of service is marked by large
kilowatt hour consumption per customer, small time diversity of
dmand, high load factor, relatively low investment in electric
system per kilowatt of demand and low cost of service per kilowatt
hour. The use of service is almost entirely large industrial power,
with only a relatively small amount of lighting. The number of this
class of customers is very small.

To serve all these various classes of custaners there is
required in the usual electric power canpany four distinct types of
property, as follows:

Generating equipment, to generate electric power at a
relatively low voltage and deliver it either to the transmission equip-
ment, or to the distribution system equipment or both.

Transmission equipnmt, to "step-up" the power delivered to
it to high voltages of the order of 22 kv. to 220 kv., transmit it to
local load centers and there deliver it to the distribution substation,
either directly or through the medium of other transmission substations
and lower voltage transmission lines. The transmission equipment may
and usually does include both transmission substations and transmission
lines.

Distribution substaticn equipment, which ”steps-down" tin
voltage of the power delivered to it to voltages of the order of 2.3 kv.
to 6.9 kv and delivers it to the distribution system equipment.

5.

Distribution system equipment, which delivers the electric
power to the customers, including all of the residential, commercial
lighting and commercial power class and to some of the industrial
power class. The distribution system consists of primary circuits
(2.3 kv. to 6.9 kv.), distribution transformers and their associated
equipment, secondary circuits (115 to 460 volts), services, meters
and in some cases building wiring and equipment.

All of these types of property are used simultaneously by
certain classes of service, though not all classes of service use all
types of property. Ordinarily the residential, commercial lighting
and commercial power classes will use all four types of propr
simultaneously. The industrial power class may use only the generating
equipment and part of the transmission line, as is shown in Figure 2,
"Simplified Diagram of an Electric Power System"; or may us all four
types of equipment, as shown in the same figure. Since carrying
charges on the value of that part of the electric system used and
useful in supplying electric service are a major part of the cost of
supplying service, in any attempt to determine the prOper rate for a
certain class of service the value of types of property used simultan-
eously by two or more classes of service must be properly allocated
against the classes by which it is used.

A further complication of the problem of allocation is
introduced by geographic location, in many instances. In some
companies the rate for a certain class of service is the same regard-
less of the geographic location of the territory served; in many others,
particularly those in which rate negotiations are ccnducted with the
authorities of each of the communities served, no such uniformity of
rates is possible. In such cases different rates for the same class of
service usually prevail for the different communities,even though they
are served from the same electric power company and in general with
the same equipment.

Figure 1 ”Production and Transmission System" will serve
to illustrate the complexity of geographically allocating generating
and transmission equipment for a system of only moderate size.
Figure 8 "Simplified Diagram of an Electric Power System” is a
simplified diagram of part of Figure l and in addition shows a small
part of the distribution substation and distribution system equipment
involved; this figure will illustrate the same complexity of geographical
allocation as it applies to distribution substation and distribution
system equipment. Referring to Figure 2, it is apparent that the
generating equipment serves customers of all classes both inside and
outside the area in which the rates are assumed to be in dispute. Tln
same is true of the transmission system, including the transmission
substations and both the high voltage and the low voltage transmission
lines. In addition, distribution substations located inside the area
serve customers of several classes located inside the area as well as

6.

customers located outside the area; distribution substations located
outside the area do likewise. Distribution systems originating inside
the area serve customers both inside and outside the area, as do
distribution systems originating outside the area.

PROPERTY VALUES TO BE ALLOCATED

Primarily the allocation of property against the various
classes of service is an allocation of dollar value, rather than an
allocation of actual physical equipment. Thus the value of the
property involved must be determined.

The determination of value is a matter of actual physical
count in the field of the various elements involved in the electric
system. This must be done by trained and competent engineers, by a
disinterested group whose technical ability and honesty are above
question and who work to a considerable extent under the direction of
the State Public Utilities Commission. After the physical count a
fair cost value per unit must be applied by the same group of
engineers in order to arrive at the value of the property used in any
way in supplying service to those customers whose rates are being
studied.

The appraisal of value, which is the result of the physical
count and the application of unit costs, gives values of property
according to certain definite subdivisions in accordance with the
standard classification of accounts as set up by the State Camnission
authorities. These standard classifications are as follows, the sub-
divisions as shown being practically the same throughout the United
States, though their actual titles may be different from those given
here: .

FIXED CAPITAL ACCOUNTS - ELECTRIC

General Ac counts

 

Intangible Fixed Capital
Construction Overheads
Unclassified Accounts

Land .
Steam Power Plant Land

Hydro Electric Power Plant Land

Gas Electric Power Plant Land

Transmission System Land - Substations
Transmission System Land - Lines

Distribution System Land Substations
Distribution Systm Land - Lines

General Office Land

Miscellaneous Lani Devoted to Electric Operations

7.

Buildings, Structures and Improvements to Land

Steam.Power Plant Structures

Hydro Electric Power Plant Structures

Gas Electric Power Plant Structures

Transmission System Structures - Substations
Transmission System Structures Lines

Distribution System Structures - Substations~
Distribution System Structures Lines

General Office Structures

Miscellaneous Structures Devoted to Electric Operations

Generating Stations - Steam.

Boiler Plant Equipment

Prime Mbvers and Auxiliaries
Turbo-Generator Units
Electrica1.Equipment

Ndscellaneous Power Plant Equipment

Generating Stations - Hydro

Reservoirs, Dams and waterways
Roads, Trails and Bridges

water Turbines and water Wheels
Turbo-Generator Units

Electrical Equipment

muscellaneous Power Plant Equipment

Generating Stations - Gas

 

Fuel Hblders, Producers and Accessories
Internal Combustion Engines

Electrical Equipment

unscellaneous Power Plant Equipment

Transmission Lines and Substations

Poles, Towers and Fixtures
Overhead Conductors
Underground Conduit
Underground Conductors
Roads and Trails
Substation Equipment

(Distribution Lines and Substations

Poles, Tswers and Fixtures
Overhead Conductors
Underground Conduit
Underground Conductors
Substation Equipment
Storage Battery Equipment

8.

Services and Consumers Installations

 

Services

Line Transformers and Devices

Line Transformers Installation
Consumers ' Meters

Meter Installations

Installation on Consumers'Premises
Cammercial Lamps

Street Lighting Equipment
Electrical Appliances

General Equipment

 

General Equipment
Miscellaneous Tangible Capital

In making a final determination of the value of the
property to be allocated, some of the classifications given above
will be finally spread over or transferred to other accounts. Con-
struction Overheads, for example, is spread over the total amount of
construction work done and will appear as part of each item in the
final determination. Land will be assigned against the part of the
electric system for which it is used. Other accounts mist be
similarly handled, such as buildings, equipment, and other general
property, each of which may require a different method of spreading
values.

The value of the entire pr0perty cannot be determined
only by accounts; the geographical location of the equipment must
also be taken into consideration. For instance, referring to Figure 2
and assuming that the rates in Area I are being studied, the value of
the high voltage transmission lines to Division A must be found, but
not of those to Divisions B and C. Again, the section of the high
voltage transmission line from the main line to the imiustrial power
customer served directly from the high voltage transmission line does
not play'any part in serving those customers in Area 1, hence its
value must be left out of the study. As another example, transmission
substation No. 1 is used to serve Divisions A, B and C, while trans-
mission substatim No. 2 serves only part of the load of Division A;
a prOper allocation requires that the value of each substation be
determined separately. Grouping the proper values together for alloca-
tion purposes will require many divisions based on geographical
location of the equipment, these divisions being determined entirely
by the arrangement of the system being studied and the particular
purpose of the study.

9.

MODS OF PROPERTY ALLOCATI ON

There is no one undisputed method of allocating electric
system value against the various classes of electric service. There
are, however, various generally accepted methods which have been used
in formal rate cases before State Public Utilities Conmissiorsand
which therefore bear the stamp of official approval. The following
paragraphs give a brief description of these methods; no discussion
of their merits and defects will be given, since this thesis deals
only with methods of allocation.

lbthod No. 1 - The “Peak Responsibility” method of alloca-
tion is based on the theory that, since the capacity of various parts
of the electric system is determined by the maximum or peak kilowatt
load they must be capable of handling, the allocation of the property
value must be made in accordance with kilowatt demands of the various
classes of service at the time of peak kilowatt load. For instance,
referring to Figure 3 "Assumed Daily Danandeof Four Classes of Customers"
the kilowatt demands of the various classes of service at the time of
system peak kilowatt load (6 to 7 P.M.) is

Kw Demand

 

 

at time of System Peak fi of System Peak Load
Class A 100 10%
Class B 100 10
Class C 330 80
Class D - ..______"
Total 1,000 100$

By this method the value of the electric system would be
allocated 10% against Class A, 10% against Class B, 80% against Class C
and none against Class D.

Method No. 2 - The "Non-Coincident Durand“ method of alloca-
tion is based upon the maximum kilowatt demands of each class of
service regardless of when the maximum demands ooctn‘, and the value of
the electric system is allocated against each class of service in the
proportion of its maximum demand to the smn of the maximum kilowatt
demands of all the various classes of service. Referring to Figure 3
these figures would be

Max.KwDemani %omenofa11Max.Danamis

Class A 100 6.2.51
Class B 500 31.25
Class 6 800 50.00
Class D 200 12.50

By this method the value of the electric system would be
allocated 6.25% against Class A, 31.2576 against Class B, 50% against
Class C and 12.5% against Class D.

10.

Method No. 3 - The "Phantom Custaner" method of allocap
tion is based on the non-coincident maximum demands of the various
classes, the possible output in kilowatt-hours of the system at
100% load factor and the actual kilowatt-hours used by each class
of service. A portion of the value of the electric system, in the
ratio of the actual kilowatt-hours output of the system to the
possible output at 100% load factor, is allocated against each of
the various classes in the proportion the kilowatt-hour output to
each class bears to the actual kilowatt-hours output; the remainder
of the value is allocated against each of the classes in the proportion
its excess kilowatt demand (maximum demand minus average demand) bears
to the sum of the excess demands of all classes of service. Referring
to Figure 3 and scanning figures for daily kilowatt hours, the follow-
ing is the basic data and percentage allocations:

s of
Max. Kw. Daily Average Excess Investment
Demand Kw-hr Demand Demnd Allocated
Class A 100 2,400 100 . - 10 .05
Class B 500 4,500 187.8 312.5 34.4
Class C 800 2,300 ‘ 96.0 704 44.9
Total 1,000 9,500 390 1204 100.015
System 1,000 9,500 396 604
Phantan 14,500

Possible 1,000 24,000 1,000

Method No. 4 - The -'Kw-hr Use" method of allocation is based
entirely on the kilowatt-hours output to , each class in proportion to
the total actual output of the system, and the value of the system is
so allocated. Using the kilowatt-hour figures assumed for the I'phautosm
custaner' method of allocation, the following figures would hold.

i of Total '
Dai Kw-hr Dag: Kw-hr
Class A 2,400 25.3‘
Class B 4,500 47.5
6133. O 2.3m 24.8
Class D 300 3.2

Total 9,000 100.0%

11.

Method No. 5 - The "Number of Custaners" method of
allocation is based entirely on the number of customers of each
class and the value of the system.is allocated in the proportion
the number of customers of each class bears to the total number of
customers of all classes. With assumed figures for numbers of
customers, the results would be as follows:

 

Number of f of T otal
Customers Number of Customers
Class A 2 .055
Class B 145 4.40
Class C 3,150 95.45
Class D 3 .09
To tal 3 , 300 100 .00$

Method No. 6 - The "Gross Income“ method of allocation
is based on the ratio that the gross income from each class bears to
the total gross income from.all classes and the value of electric
system.is so proportioned. With assumed figures for gross income
from.aach class, the following will hold good:

 

 

Gross Annual %»of Total
Income Gross Income_
Class A $ 3,000 6%
Class B 15,000 30
Class 0 30,000 60
Class D 2,000 , 4
Total $50,000 100%

FINAL DATA NECESSARY FOR ALLOCATION BY EACH METHOD

Allocation by Methods 4, 5, and a 1‘5 relatively simple;
having the proper data as to kilowatt-hours output, number of customers,
or gross income, the allocation becomes merely a matter of multiplying,
by the proper ratio, the value of the property used simultaneously by
the class of service whose rates are being studied and other classes
of service. One ratio will not hold good, of course, for all parts
of the system, because as has been said before all parts of the system
are not used simultaneously by all classes of service, and neither does
every study include all parts of the entire system. However, determining

12.

figures as to kilowatt-hours output to, number of customers of

or gross income from any class of service for any given geographical
area is a relatively simple and relatively accurate process,
since it requires only the laborious but simple collection of
information from.1edger pages after the geOgraphical boundaries
of the area have been determined. It is sometimes necessary to
make assumptions where accurate information is not readily
available; very few assumptions are necessary, however, and their
numerical size and the part they play in the final formula of
allocation is so small that even a large percentage of error in
the assumptions would cause only a very slight and negligible
error in the final results.

Allocation by methods 1, 2, and 3 is not so simple.
Here the basis of allocation is kilowatts demand or a combination
of kilowatts demand and kilowatt hours use or output. For instance,
to properly allocate the value of the various parts of the system of
Figure 2 against the residential class of service in Area I, under
the plan of allocation most often used it has been necessary to
determine the kilowatts demand of or kilowatt hours output to that
group of customers at several different times of day snd.year and
at several points on the system, including the generating station,
transmission substations Nos. 1 and 2, distribution substations
a, b and c, and at several other points. It has also been necessary
to know the demands and kilowatt hours of other classes of service
and other groups of customers at these same times and locations.
Here lies the weakness of such a plan; very little of such data is
available from actual operating records, hence much of the data for
the various locations on the system must be calculated.

For instance, referring to Figure 2 and assuming a study
of the residential rates within Area I; the process often followed
is as described below. Graphic recording instruments are installed
at typical customers premises, at the primary or secondary side of
the distribution transformers and at points on the distribution
primary in such locations that only the data for one certain class
of service will be obtained. In this way the characteristics of the
loads of each class of service will be measured. With these data as
a basis, the next step in the compilation of the measured results
and the determination of average demands per customer or per kw-hr
sold for each hour, the kw-hr output to the average customer of each
class, load factors of each class of service, and power factors.
After these data are obtained, the demands and kw-hr output to each
class of service must be determined for points at each distribution
substation, each transmission substation and at the generating plant.
It is obviously impossible to install meters to measure the demand and
kilowatt hours of one class of service in locations such as the
substations, transmission lines and generating station, since these
are used simultaneously by several classes of service. Hence the
demands and kilowatt-hours at these points must be calculated.

13.

These calculations require many assumptions as to load factors,
power factors, diversity factors and loss factors. Engineering
opinion and knowledge of the factors to be assumed in any given
case may and usually does vary widely and,no matter what
numerical figures are assumed, honest dispute is certain to
arise. The large number of factors to be assumed, together with
their possible range of numerical variation, is so great that the
actual final allocation values may vary over a wide range with
different assumptions. The figures assumed by one group of
engineers will seem unreasonable to another group, and any figures
assumed as a compromise between divergent opinions will satisfy
neither group. ‘

A Other drawbacks to this procedure are the necessity for
the installation and attendance upon thousands of graphic meters of
all sorts, a great many times more of such meters than the utility
normally owns; the long elapsed time for obtaining the meter data,
as this must include at least a year in order to cover all conditions
of load; and the thousands of compilations involved in studying the
charts to arrive at only preliminary data.

Under the scheme outlined in this thesis, very few
assumptions are necessary and such figures as must be assumed cannot
vary greatly enough to cause final allocation figures to vary between
other than very narrow limits. The accuracy of the final allocation
is well within the limits of accuracy of properly maintained meters
at various points in the system.

Briefly, with this scheme and for the problem assumed, it
is not necessary to know the demands and kilowatt hours of the Area 1
residential class at the generating station, the transmission substations
and the high and low voltage transmission lines; it is only necessary
to know these demands and kilowatt hours at the distribution substations.
These figures can be easily and accurately determined, as will be
described later. There is no necessity for the installation of graphic
meters and the compilation of data from many individual charts, with its
attendant great expense.

By this method the property value of each part of the system,
beginning with the generating station and ending with the distribution
system, is allocated against the next successive part of the system
toward the custaner. Thus, in Figure 2, the value of the generating
station and transmission substation No. l is allocated against the
high voltage transmission lines to each Division. The value of the high
voltage transmission line to Division A, plus the value of tie generating
station and transmission substation No. 1 allocated against it, is
then allocated against transmission substation No. 2 and against those
customers served directly frcm the high voltage transmission line.

Then the value of transmission substation No. 2, plus its accumulated

14.

allocation of generating station, transmission substation No. l

and high voltage transmission line to Division A, is allocated
against the low voltage transmission lines. This process of
allocation is continued as far as necessary. Not until the distri-
bution substations are reached need the demands and kilowatt hours
of the Area X residential class be used.

The chief advantage of this method of allocation is the
fact that accurate data for the proper allocation is usually
readily available from operating records of the various generating
stations, substations, and customers and, wherever calculations
are necessary, very few assumptions need be made. Even where
assumptions must be made, in most cases commonly accepted figures
are available and there is little likelihood of difference of
opinion among competent engineers. Where assumptions mist be
made, they are relatively unimportant and of such minor value, that
even a wide variation in the figures assuned will result in only
unimportant differences in the final allocation figures.

Using the scheme outlined, for the conditions as assumed
in Figure 2, the following final data will be necessary for proper
allocation of the values of different parts of the systan for any
period studied.

Method No. 1 - Peak Responsibility

 

l - Kilowatts of denand, measured at generating station and
transmission substation No. l, at time of peak demand
at that location.

a - Of entire system
b - of Division A
c - Of transmission substation No. 2

2 - Kilowatts of demand, measured at transmission substation No. 2,
at time of peak demand at that location.
a - Of transmission substation No. 2
b - Of distribution substations a, b, and c.
c - Of customers in Area I served directly from the
low voltage transmission lines.

3 - Kilowatts of demand, measured at distribution substations a, b,
and c, at time of peak danand at those locations.
a - Of distribution substations a, b, and c.
b - Of each class of service in Area I served through
distribution substations a, b, and c.

15.

Method No. 2 - Non-Coincident Demand

1 - Kilowatts of peak demand, measm'ed at generating station
and transmission substation No. l
a - 0f each Division
b - Of transmission substation No. 2
c - Of customers in Division A served directly from
high voltage transmission line.

2 - Kilowatts of peak demand, measured at transmission
substation No. 2

a - Of distribution substations a, b, and c.

b - Of all other distribution substations served
through transmission substation No. 2

c - Of customers in Area I served directly from low
voltage transmission lines through transmission
substation No. 2.

d - Of all other customers in Division A served directly
from low voltage transmission lines through
transmission substation No. 2.

3 - Kilowatts of peak demand, measured at distribution
substations a, b, and c.
a - Of each class of service in Area I served through
distribution substations a, b, and c.
b - Of each class of service outside Area I served
through distribution substations a, b, and c.

Method No. 3 - Phantom Customer

1 - Kilowatts of peak demand and of average demand of, and kilowatt-
hours to, measured at generating station and transmission
substation No. l

a - Entire system

b - Each Division

c - Transmission substation No. 2

d - Customers in Division A served directly from high
voltage transmission line.

2 - Kilowatts of peak demand and of average demand of, and kilowatt
hours output to, measured at transmission substation No. 2
a - System served by transmission substation No. 2
b - Distribution substations a, b, and c.
c - All other distribution substations served through
transmission substation No. 2
d - Custcmers in Area X served directly from low voltage
transmission lines through transmission substation No. 2
e - All other customers in Division A served directly from
low voltage transmission lines through transmission
substation No. 2

16.

3 - Kilowatts of peak demand of, and kilowatt hours output to,
measured at distribution substations a, b, and c.
a - System served by distribution substations a, b, and c.
b - Each class of service in Area X served through distri-
bution substations a, b, and c.
c - Each class of service outside Area X served through
distribution substations a, b, and c.

4 - Total possible kilowatt hours output at 100% load factor and
measured peak demands above, of
a - Generating station and transmission substation No. l
b - Transmission substation No. 2
c - Distribution substations a, b, and c.

Method No. ~4 - Kilowatt Hour Use

 

l - Kilowatt hour use, measured at customers! meters, of
- All customers of entire system, total

All customers of Division A, total

All customers of Area X

Each class of service in Area X

@069
l

Method No. 5 Number of Customers

 

1 - Number of customers
a - Total in entire system
b - Total in Division A
c - Total in Area X
d - Each class in Area X

Method No. 6 - Gross Incane

 

1 - Gross income from customers in
- Entire System
Division A

Area X

Each class in Area X

9100'”
I

ORIGINAL DATA AVAILABLE FROM COMPANY RECORIB

The sources of data for the allocation of value here
described are the usual records kept by most operating companies in the
normal routine of business. Such records as are kept in the commercial
and Operating departments of the company will furnish most, if not all,
of the necessary data.

17.

The commercial department ledgers will list the nane of
each customer, the location of the premises served, the rate schedule
(or class of service) at which the service is supplied, the kilowatt
hours used each month, and the net bill by months. The ledger pages
are almost invariably arranged by location of the premises served,
so that pages representing accounts for premises located on a given
street are arranged in the ledgers in the nmnerical order of the
addresses on that street. The groups of ledger pages, each group
representing the premises served'on a given street, are arranged in
the ledgers alphabetically by street names. In addition, the sets
of ledgers are arranged by rate schedules, or classes of service, so
that the set of ledgers representing residence customers, for example,
is entirely separate frcm the set representing commercial lighting
custaners and other classes.

With such a set-up of ledger pages, groups and sets, it is
a relatively easy matter to determine the number of customers, kilowatt
hours use, and the net bill for any given class of service, for any
given period and for any area whose boundaries are known. A count
from the ledger pages will furnish this information and, while laborious,
does not require any difficult calculations, hence can be readily made by
the usual clerical force of the ccmpany.

In addition to the ledger pages spoken of, the comercial
department will also have additional data on all industrial power
custaners and on many commercial lighting and commercial power custoners.
This additional data will consist of graphic demand charts showing
kilowatt or kilovolt-ampere (or both) demands of each customer at all
hours of the day for the entire period since service was first supplied
to that custcmer or, at the least, for the past three to five years.

In addition, graphic power factor charts, made during periodic checks
and covering periods from several days to a week, are usually also
available for most of these custcmers.

From the Operating department records are available daily log
sheets for each attended generating station and attended substation; '
for each unattended or automatic generating station and substation a
weekly or monthly summary sheet will be available. ,

The daily log sheets will show periodic (usually hourly, but
sanetimes half-hourly) indicating ammeter, voltmeter and sometims power-
factor meter, readings for each primary distribution circuit served
from the substation, for each street lighting circuit served from the
substation, for incoming and outgoing transmission lines, and for special
groups of apparatus within the substation, such as distribution substa-
tion transformer banks, street lighting transformers, rotary converters
and their transformers, and similar combinations of equipnent. A
simplified typical system and the various points at which such measure-
ments are usually made is shown in Figure 7, "Data Available for Demand
Analysis". Similarly, integrated kilowatt hour input and output readings

18.

are also shown on these daily log sheets for many of the points
at which indicating meter readings are taken.

The weekly or monthly summary sheets for the unattended
generating stations and substations will usually give only the
integrated kilowatt hour input and output readings at certain points
within the generating station and substation, as shown in Figure 7,
the interval between readings being a week or a month.

In addition to the daily log sheets and the weekly or
monthly summary sheets for generating stations and substations, the
Operating department will have much other information necessary for
the allocation study. Such information will include maps showing
the geographic location of generating stations, transmission lines,
substations, distribution primary lines, distribution transformers,
street lighting lines and street lights; system diagrams, showing the
electrical arrangement Of the entire system; station diagrams, giving
similar data for stations; and equipment card files containing
miscellaneous mechanical and electrical data on the major items of
equipment on the entire system. From these various sources can be
Obtained the vast majority of data necessary in those cases where
the log sheets and surmnary sheets do not give readings at a sufficient
number of points and calculation must be resorted to.

NETHDD OF USING ORIGINAL DATA TO DETERI‘HTE FINAL DATA NECESSARY

It is not possible to determine offhand what the peak
demand of a given part of the electric system is nor just when it
occurs. Hence it becomes necessary to determine all the hourly
demands for the period covered by the study, in order to select the
maximum demand and to know when it occurred. Sometimes the figure
is not available directly, but must be reached by subtracting from
the total demand the demand of other parts of the system; to get
this data may be likened to measuring the depth of water in all
parts of an ocean where a heavy sea is running and the contour of
the bottom of the ocean is rugged. In order to make such an analysis,
demands must be determined and plotted at various points on the
system in the form of curves similar to that shown in Figure 6,
"Typical Demands of Parts of a System”, which has been built up for
reference to Figure 2 conditions.

A strictly accurate analysis of conditions will require
the building up of demand curves for each class of customers, each
distribution substation, each transmission substation, each trans-
mission line and each generating station for every hour Of every day
of the period for which the study is to be made, a laborious job
with a tremendous amount of detail. However, a preliminary study of
system conditions, coupled with an intimate knowledge of the system
and the typical characteristics of the demand curves of the various

19.

classes of service, will enable the engineer to determine dates
and times Of the day at which such an analysis will give results
accurate within the degree of accuracy of the meters installed
at the variom points on the system. Such a preliminary away
will usually result in the choice of one day each month and a
fourteen or sixteen hour period for each of these days as the
periods for which the study must be made in detail, resulting
in a study requiring only 168 sets of calculations aswagainst
the 8,760 sets of calculations required for a complete hourly
study of a one year period. The proper choice of days and hours
depends entirely on the individual system, Of course, but the
limits quoted above have proved in one case to give results
accurate within one percent plus or minus, the maximum accuracy of
the indicating meters used in the variom substations; greater
refinement than this is unnecessary and illogical.

Referring to Figure 2, the first group of figures necessary
in this scheme of allocation are the danands of and kilowatt-hours
output to each of the high voltage transmission lines to Divisicns
A, B and C, as well as the maximum demand for the entire group, at
the generating station and transmission substation No. l. The
generating station and transmission substation in this case can be
considered as one unit. Referring to Figure '7, the operating record
data here will give amperes, volts and kilowatt hours hourly by
circuits and for the station as a whole. The umal standard calcu-
lations will provide the demand figures for the curves covering the
period studied. Kilowatt hour output figures are directly available.
Calculation will provide figures for average danands and total
possible kilowatt hour output at 100% load factor and measured peak
demand, as required by the ”phantom customer" method of allocation.
Hence the value of the generating station and the transmission sub-
station NO. 1 can be allocated against each of the high voltage trans-
mission lines to the Divisions, and no controversial items such as
assumptions of any sort have been introduced in the allocation.

It is now necessary to determine the demands, at trans-
mission substation No. l on the 132 kv side, of transmission substa-
tion NO. 2 and of the customers served directly from the high voltage
tranmnission line. The demands and kilowatt hours at the customers'
premises on the 132 kv side are available directly fran readings at
the customers'meters. These must be translated to the l32 kv bus at
transmission substation NO. l and the results subtracted from the
figures for the entire line in order to get the data for transmission
substation NO. 2. The translation must be made by calculation, but
since all factors are known, no controversial items are introduced.
The same is true of the average demand and possible kilowatt hour
output for the "phantom customer" method of allocation.

This same general process can be followed down to and
including the demands and kilowatt-hour output of the distribution
substations, on the low voltage side. Some Of the distritution
substations very probably will be unattended and there will be
available only a weekly or monthly summary of the kilowatt-hours
output of the substation as a whole; no hourly readings of smpares,
volts and power factor for the substation as a whole and for each
circuit will be available. However, to determine demand values
for the substation as a whole, it will be sufficiently accurate to
use the known values of demands for the attended substations as
a bass and to multiply these base figures by the ratio of the
unattended substation kilowatt-hours output to the attended sub-
station kilowatt-hours output. The sum of demands for the attended
and the unattended substations will give the demands of the group.
[hen a distribution substation serves loads both inside and outside
the area being studied, its value can be reasonably accurately
allocated on the basis of the relative kva of distribution trans-
former capacity inside and outside the area served from the distri-
bution primary circuits fed by the substation.

Here it becomes necessary to determine the demands of
and kilowatt-hours output to each of the various classes of service
supplied through the substation. To do this, analyses of typical
residential and commercial lighting distribution primary circuits
within the area in which the rates are to be studied must be made.
In choosing the circuits to be analyzed, an intimate knowledge Of
the distribution system is necessary, since the circuits chosen
must serve typical customers, rather than unusual ones. In choosing
the residential circuits to be studied, for example, it is necessary
that the average kilowatt-hour use of the customers on the circuits
to be studied should closely approximate the average kilowatt-hour
use of the total group of residence custoners in the entire area
studied. The same requirement is not so necessary for the commercial
lighting circuits, but it is highly desirable.

In making the selection of circuits of each type to be
analyzed, it is usually necessary to choose tentatively two to three
times the number of circuits it is finally desired to study, this
tentative choice being based on the assumed characteristics of the
average use per custaner on each of the circuits. The average kilowatt-
hour use per customer in the entire-area studied is determined by first
establishing the boundaries of the area by street name and number;
from the commercial department ledgers is determined the total kilowatt-
hour use of each class Of service and the total number of customers Of
that class, these figures serving to determine the average use per
custaner. A similar analysis for each Of the circuits tentatively
chosen as typical will give the average use for the customers on that
circuit, and will serve as the basis for the elimination Of those
tentatively chosen circuits which are not suitable for the final
analysis. ‘

21.

After the final choice of circuits to be analyzed, the
daily log sheets will give the necessary data for the calculation
of demands and kilowatt hours at the distribution substations for
each circuit. This data consists of the circuit amperes, volts,
power factor and kilowatt hours. Grouping the data for all the
circuits of each given class analyzed will provide a reasonably
accurate picture of the demands of each class of customers. To
determine the demands and kilowatt hours at the substation of all
of the customers of each class within the area, it is only
necessary to multiply the figures obtained from the circuit
analysis by the ratio of the total kilowatt-hour use of all the
custcmers of that class within the area to the total use of all
the custaners of that class on the circuits analyzed. Demands and
kilowatt hours detennined in this way are the demands and kilowatt
hours at the distribution substation bus; they include demands an!
kilowatt hours at the customers' premises plus losses in the
secondaries, distribution transformers and primaries, together with
all the effects of diversity from the customers' premises to the
distribution substation.

The selection of distribution primary circuits serving
residential custcmers only, or serving residential custansrs in such
prepertion that the inclusion (r other classes has no practical effect,
can be done satisfactorily in most systems. ‘lhe same thing is true,
but not to such a great extent, for distribution primary circuits
serving cannarcial customers.

‘i'he probability of selecting such circuits for retail
power or industrial power customers is relatively remote, and where‘
such a choice cannot be made, recourse met be had to analyses of
customers' demand charts from the commercial department. The first
step in the analysis of customers' demand charts is the division of
custanars into groups based on type of business or load factor. This
division into groups is made necessary by the fact that charts are
usually available for some of the customers but not for all of them,
and the load characteristics of customers served at the same rate
schedule, particularly in the commercial power and industrial power
classes, may vary considerably from each other, as is evident in
Figures 4 and 5. Such a division into groups can usually be made
on the basis of type of business. A typical division might include
such groups, for instance, as Large Retail Stores; Hospitals; Hotels;
Mass Production Factories; Custom Production Factories; Office Buildings;
etc., the actual grouping being entirely dependent upon local conditions
and usually being fairly clearly indicated by a preliminary inspection
of those customers' demand charts which are available.

After the division of the customers into groups, the demands
of the customers within each group for whan demand charts are available
are compiled frcm the charts and than consolidated. The demands of the
entire group are then obtained by multiplyiig the consolidated demands by

the ratio of the kilowatt-hour use of the entire group to the
kilowatt-hour use of the customers for whom the demands are known.
The consolidation of the demands of all the groups served at any
one rate schedule will result in the demands of all the customers
served at that rate schedule.

During the process of determining these consolidated
demand and kilowatt-hour figures, it will be necessary to take into
account the points on the circuits at which the demands and kilowatt
hours as shown by the customers' charts and meter readings are
located, in order that the figures obtained may evaitually be
translated into figures at the distribution substations.

For instance, measurements on the primary side of a trans-
former bank include transformer and secondary circuit losses, while
measurements taken on the secondary side of the transformer bank do
not include the losses through the transformers. Neither measurements
include primary circuit losses from the distribution swstation bus
down to the point at which the measurement is taken. To translate
measurements taken on the secondary side of a transformer bank into
terms of measurements on the primary side is a simple process of
calculation, since transformer electrical data is well knownlor can
readily be obtained; hence no controversial items of importance are
introduced here.

After these measurements have been translated to the
primary side of the transformers,there ranains the question of losses
in the distribution primary circuit. These are relatively easily
determined and allocated against the proper classes of service. From
the demands and kilowatt hours of all classes of service at the distri-
bution substation bus there met be subtracted the demands and kilowatt
hours of the residential and comrcial lighting classes of service
at the substation bus, as determined fran the circuit analyses previously
referred to. The remainder is the combined demands and kilowatt hours
of, the commercial power and industrial power customers served from the
distribution substations; it includes the losses in the distribution
circuits‘up to the point and which measurments of demands and kilowatt
hours are taken at the customers' premises, in addition to those
measured demands and kilowatt hours. Iran this remainder is subtracted
the measured demands and kilowatt hours of the comercial power and
industrial power customers, leaving a remainder which is losses in the
distribution circuit due to these customers' loads. These losses can
then be allocated to each of the two classes of service on the basis
of loss factor, as described in an article on page 59 of the July 14,
1988 issue of Electrical World, entitled "Load Factor - Equivalent
Hour Values Compared", by Heller and Woodrow.

It will usually be found that the circuits serving residential
customers and those serving commercial lighting customers will also
serve commercial power customers and perhaps industrial power customers.

23.

Careful selection of circuits usually will eliminate these customers
almost entirely from the analyses, at least to such an content that
their influence is unimportant. If they cannot be so eliminated,
however, and it is desired to eliminate their influence practically
entirely from the final figures, it can be done. This involves

the determination of dmnands and kilowatt hours as already described,
for each class of service. Then the figures as determined for each
class of service, (such as conmercial lighting, commercial power and
industrial power can be used to eliminate (from its analysis of the
residential service circuits, for example) the effect of those
classes of service, and new figures arrived at for each class of
service. This process will render the results obtained nore accurate
than tts first determination and a second similar process will render
them even more accurate. It has been found that the second of these
processes will produce so little change in most cases that a third
similar manipulation is of little value; sometime even the second
change is unnecessary.

This process completes the determination of all data
necessary for allocation by the peak responsibility and non-coincident
demand methods. For the phantom customer method there remains to
be determined the total possible kilowatt hours output of the various
, parts of the system at its peak dmnand and 100% loai factor. This is
urely a matter of multiplying the peak demand by the total number ‘
of hours in the period for which the study is made, usually one year.

ACTUAL ALLOCATION OF PROPERTY - TYPICAL CASE

In order to illustrate a typical case of allocation,
figures are assumed below for a systun as shown in Figure 2, in which
it is also assumed that the residential rates in Area I are being
studied. All property values as given include the proper distribution
of the General Accounts; Land Account, Buildings, Structures and
Improvements to Land Account; and General Equipment Account. For
simplicity's sake only one method of allocation, the peak responsibility
method, is shown and it has been assumed that peak demands occur on the
varioie parts of the electrical system at the same time and day.
Instrument readings are seemed as available in accordance with the
details of Figure 7 and in addition it is assumed that analyses of
distribution primary circuits and customers' charts have been made
and demands of the various classes of custcmers determined at the
distribution substation.

In order to make the final allocation of the distribution
system in this example, it is necessary to subdivide the "Overhead
Conductors" subdivision of the "Distribution Lines and Substations"
account into two parts, one part including only the primary circuit
conductors and the other including the secondary circuit conductors.
It is assumed that this has been done and that the value of the Poles,
Towers and Fixtures account has been allocated against the primary

 

24.

circuit and the secondary circuit in proportion to their relative
circuit-miles .

Again for simplicity's sake, no underground distribu-
tion system is assmned to be involved in this study.

‘t.

Generating Station and Transmission Substation No. l

Appraisal value of generating station and
transmission substation No. 1 $20,000,000 ' . .

System peak demand measured at 132 kv side
of transmission substation No. 1 100,000 KVA

Demand of Division A at time of system peak
demand, measured at 132 kv side of trans-
mission substation No. 1 50,000 K'VA

Value of generating station and transmission
substation No. 1 allocated against high
voltage line to Division A
(30,000 1» 100,000) 1 $20,000,000 $10,000,000

High Voltage Line to Division A.

Appraisal value of high voltage line to

Division A $3,000,000
Portion of value of generating station and

transmission substation No. l allocated

against this line 10 000 000
‘ Total £13 , 000 ,000

Denand of Division A at time of systan
peak demand, measured at 132 kva side of
transmission substation No. 1 50,000 KVA

Danand of transmission substation No. 2 at
time of system peak demand, measured at
28 kv side of substation but calculated
back to 132 kv side of transmission sub-
station NOe 1 7 40.000 KVA

Value of high voltage transmission line,
generating station and transmission substa-
tion Ho. 1 allocated against transmission
substation No. 2 (40,000 9 50,000) 1 $13,000,000 $10,400,000

Transmission Substation No. 2

Appraisal value of transmission substation
No. 8
Portion of value of high voltage transmission
line, generating station and transmi ssiai
substation No. 1 allocated against trans-
mission substation No. 8
Total

Peak demand at transmission substaticn No. 2,
measured at 22 kv side of substation

Demand of low voltage transmission lines
serving distribution substations a, b,
and c and other loads at time of peak
demand on transmission substation No. 2,
measured on 4 kv side of distribution sub-
stations and at 22 kv side of custcmers'
installations and calculated back to 22 kv
side of transmission substation No. 2

Value of high voltage transmission line,
generating station, transmission substation
No. l and transmission substation No. 2
allocated against low voltage transmission
lines serving distribution substations a, b,
and c and other loads
(22,800 e 38,000) 1 $12,000,000

Low Voltage Transmission Lines

Appraisal value of low voltage transmission
lines serving distribution substations a, b,
and c and other loads

Portion of value of transmission substations
Nos. 1 and 2, high voltage transmission line
and generating station allocated against low
voltage transmission lines serving dis tribu-
tion substations a, b, and c and other loais

Total.

Peak demand of these low voltage transmission
lines at transmission substation No. 2,
calculated at 22 kv side of substation

$1,600,000

10 400 000
12,000,000

38,000 KVA

22,800 KVA

$7,200 ,000

$800,000

$8,000,000

22,8002KVA

26.

Demand of distribution substations a, b and 0
at time of peak demand on these low voltage
transmission lines, measured at 4 kv side
of distribution substations and calculated
at 22 kv side of transmission substation No. 2 17,100 KVA

Value of low voltage and high voltage trans-
mission linas, transmission substations and
generating station allocated against distri-
bution substations a, b and c.
(17,100 0» 22,800) 1 $8,000,000 $6,000,0Cn

Distribution Substations a, b and c.

Appraisal value of distribution substations

a, b and c $500,000
Portion of value of transmission lines, trans-

mission substations and generating station

allocated against distribution substations

a, b and c $6,000,000
Appraisal value of distribution primary

circuits served from distribution substa-

tions a, b and c. $509,000

Total $7,000,000

 

Peak danand at distribution substations a,
b and 0, measured at 4 kv side 16,8)0 KVA

Demand of residential class of service in
Area I, at time of peak demand at distribu-
tion substations a, b and 0, measured at 4 kv
side of distribution substations 15,960 KVA

Value of distribution primary circuit, distribu-
tion substations, transmission substations,
transni ssion lines and generating station
allocated against residential class of service
in Area I -
(15,960 e 16,800) 1 $7,000,000 $6,650,000

(Note - Up to this point the peak responsibility method of
allocation. has been followed and all property values involved have
been so allocated. Now, however, in the remaining parts of the system
from here to the custaner there is much less simultmeous use of any
certain part of the system by several classes of service, and more
accm'ate allocation is possible. In fact, no general simultaneous
use, by several classes of service, of any given type of equipneut
will exist from here on. Individual cases of such simultaneous use
will occur, however.

 

27.

Distribution transformers serving residential customers
in any given area can be actually counted in the field, as can
distribution secondary circuits, services, meters and installa-
tions on customers' premises. The distribution transformers and
secondary circuits my be involved in some few cases in serving
both residential customers and commercial lighting customers,
but the values involved in these few cases are so small in pro-
portion to the total values that any reasonable allocation will
affect the total allocation figures only to a very small degree.
It has been assumed here that the property values involved in
these few cases of simultaneous use have been allocated on the
peak responsibility basis, the demand figures used being demands
at the distribution substations as determined frcm circuit
analyses. These figures are applied only according to the loads
actually served from the distribution transformers and secondary
circuits involved in simultaneous use; no general allocation of
all distribution transformers and all distribution secondary
circuits is necessary.

The values of services, meters and installations on
custaners' premises to be allocated against the residential class
of service are a matter of actual field count.)

Distribution Transformers - Distribution Secondary Circuits -
Services - Meters - Installations on Customers' Premises

Value of distribution primary circuit, distribution
substations, transmission substations, transmission
lines and generating stations allocated against
' residential class of service in Area I $6,650,000

Value of specific item of other distribution property
in Area I allocated against residential customers
in Area X

Distribution transformers, allocated in vast
majority of cases by actual field count and,
in a very few cases of simultaneous use, on

peak responsibility basis . $800,000
Distribution secondary circuits, allocated as

of distribution transformers $400,000
Services, allocated by actual field count $600,000
Meters, allocated by actual field count $600,000

Installation on customers' premises, allocated
by actual field count $50,000

Total Electric System Pr0perty Value
allocated to residential customers
in Area I

 

$9,100,000

 

GETTIRALOOMEENTS

The plan for allocating property values, as described in
the preceding pages, is primarily a plan for determining data for
any of several different commonly accepted methods of allocation.
It involves the minimum of assumptions and hence the minimum of
controversial features, which is its strongest feature.

Its actual use is relatively simple, as is shown by the
example of allocation illustrated. While a more complex electrical
system than that shown in Figure 2 will involve considerably more
detail than has been shown in this paper, yet the principle renains
the same and is equally applicable to the simple and to the canplex
system.

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BIBLIOCRAPHY

 

BIBLIOGRAPHY

mac.
Dapreciation of Public Utility Properties - Riggs, H. E.
Chapter VI
Economics of Public Utilities - Nash, L. R. - Chapter VII
Outlines of Public Utility Economics - Glasser, M. G.
Public Utility Rate Structures - Nash, L. R. - Chapter XI

Rate-Making for Public Utilities - Lyndon, L.
Chapters III and IV

Standard Handbook for Electrical Engineers, Fifth Edition
Section 25

Standard Handbook for Electrical Engineers, Sixth Edition
Sections 12 to 15

Theory ami Practice of Public Utility Valuation -'
Maltbie, W. H. - Chapter IV to I

The Public and Its Utilities - Raymond, W. G. - Chapter II

Periodicals

 

A. S. M. E. News, January 22, 1951

Bulletin of Taylor Society, April 1926 - Article by
John Bauer, p. 99

Electrical Engineering, March 1951 - p. 215

Electrical World,
February 28, 1896 - p. 222

January 2, 1915 - p. 17

October 21, 1922 - p. 878

October - 28, 1922 - p. 928

December 51, 1922 - p. 1431

November 7, 1925 - Article by W. J. Greene
January 20, 1926 - p. 403

May 29, 1926 - Article by W. J. Greene

August 28, 1926 - p. 427 - Article by C. F. Lacombe
September 18, 1926 - p. 575 - Article by C. F. Lacombe
October 2, 1926 - p. 701 - Article by C. F. Lacombe

January 22, 1927 Article by H. W. Hills

 

4":

Electrical World, (cont'd)
January 29, 1927 - Article by H. W. Hills
August 27, 1927 - p. 402
August 28, 1928 - p. 359
October 27, 1928 - p. 827 - Article by L. W. W. Morrow
April 11, 1951 - p. 672
August 15, 1931 - p. 289 - Article by S. B. Heath
November 19, 1932 - p. 684 - Article by Jorgensen and Matteson 11..”

National Association of Railroad and Utility Commissioners
Proceedings, 1930 - p. 319 and 347 - Article by A. Kanneburg

Ne Es Le As Enlletin.
November 1930 - p. 689 - Article by H. L. Gruehn L
December 1930 - p. 775 - Article by E. J. Cheney
February 1931 - p. 129
April 1931 - p. 247 - Article by W. Kelly

 

N. E. L. A. Proceedings, 1923 - p. 156 - Alex Dow
1931 - p. 106 - Article by Marshall and Snow

N. E. L. A. Report of Rats Research Committee, 1923 -
Statement by Alex Dow.

Public Utility Fortnightly,
July 23, 1931 - p. 67 - Article by N. M. Clark
March 3, 1932 - p. 269
July 21, 1932 - p. 72 — Article by C. S. Reed
September 29, 1932 - p. 374 - Article by John Bauer.

«ii-DOM USE ONLY .

 

 

 

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