电力需求与定价(17)

peak period loss factors when current flows are greatest [6].

The treatment of losses raises several important issues. While

total normal technical losses (including station use) vary from

system to system, if these are significantly greater than about

15 percent of gross generation, then loss reduction should have

a high priority. When engineering losses in excess of acceptable

levels are routinely passed onto the customer, this may

act as a disincentive to improvements in technical or administrative

efficiency. Losses due to theft and unpaid bills are also

often loaded onto paying customers. Here again, the issue is

whether these nontechnical losses could be reduced by appropriate

measures, or if incremental consumption always has an

unavoidable component of such losses associated with it.

Theft in U.S. systems has been estimated to average about

2 percent of gross generation, but norms in developing countries

may have to be set somewhat higher [ lo], [ 3 11. The

LRMC analysis at the generation, transmission and distribution

levels helps to establish whether these incremental costs

are excessive because of overinvestment, high losses, or both.

D. Consumer Costs

It has proved difficult to allocate part of the distribution system

investment costs to customer costs, on the basis of a

skeleton system required to serve a hypothetical minimum

load. Similarly regression analysis of past data to fit equations

such as:

(Distribution Costs) = a + b (Peak Demand)

+ c - (Number of Customers)

has not been too successful because peak demand and the

number of customers are usually highly correlated. Therefore,

general distribution network costs may be considered as capacity

costs, while customer costs are defined as those which

can be readily allocated to users. Initial customer costs consist

of nonrecurrent expenses attributable to items such as

service drop lines, meters and labor for installation. These

costs may be charged to the customer as a lump sum or distributed

payments over several years.

Recurrent customer costs that occur due to meter reading,

billing, administrative and other expenses, could be imposed as

a recurring flat charge, in addition to kilowatt and kilowatthour

charges. In general, the allocation of incremental (nonfuel)

operation, maintenance and administrative costs among

the categories: capacity, energy and customer costs, varies

from system to system and requires specific analysis. However,

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