Current through Register Vol. 49, No. 13, September 23, 2024
Subpart 1.
Information required.
Schedule B must contain the information listed in subparts
2 to
6.
Subp. 2.
Planned utility generating
facility additions.
Schedule B must contain a description of all planned utility
generating facility additions anticipated during the next ten years,
including:
A. name of unit;
B. nameplate rating;
C. fuel type;
D. in-service date;
E. completed cost in dollars per kilowatt in
the year in which the plant is expected to be put in service, including
allowance for funds used during construction;
F. anticipated average annual fixed operating
and maintenance costs in dollars per kilowatt;
G. energy costs associated with the unit,
including fuel costs and variable operating and maintenance costs;
H. projected average number of kilowatt-hours
per year the plant will generate during its useful life; and
I. average annual fuel savings resulting from
the addition of this generating facility, stated in dollars per
kilowatt.
Subp. 3.
Planned firm capacity purchases.
Schedule B must contain a description of all planned firm
capacity purchases, other than from qualifying facilities, during the next ten
years, including:
A. year of the
purchase;
B. name of the
seller;
C. number of kilowatts of
capacity to be purchased;
D.
capacity cost in dollars per kilowatt; and
E. associated energy cost in cents per
kilowatt-hour.
Subp. 4.
Percentage of line losses.
Schedule B must contain the utility's overall average
percentage of line losses due to the distribution, transmission, and
transformation of electric energy.
Subp.
5.
Net annual avoided capacity cost.
Schedule B must contain the utility's net annual avoided
capacity cost stated in dollars per kilowatt-hour averaged over the on-peak
hours and the utility's net annual avoided capacity cost stated in dollars per
kilowatt-hour averaged over all hours. These figures must be calculated as
follows in items A to I:
A. The
completed cost per kilowatt of the utility's next major generating facility
addition, as reported in schedule B, must be multiplied by the utility's
marginal capital carrying charge rate in the first year of investment. If the
utility is unable to determine this carrying charge rate as specified, the rate
of 15 percent must be used.
B. The
dollar amount resulting from the calculation set forth in item A must be
discounted to present value, as of the midpoint of the reporting year, from the
in-service date of the generating unit. The discount rate used must be the
incremental cost of capital.
C. The
figure for average annual fuel savings per kilowatt described in subpart
2, item I must be discounted
to present value using the procedure of item B.
D. The number resulting from the calculation
in item C must be subtracted from the number resulting from the calculation in
item B. This is the net annual avoided capacity cost stated in dollars per
kilowatt at present value.
E. The
net annual avoided capacity cost calculated in item D must be multiplied by
1.15 to recognize a reserve margin.
F. The figure determined from the calculation
of item E must be increased by the present value of the anticipated average
annual fixed operating and maintenance costs as reported in subpart
2, item F. The present value
must be determined using the procedure of item B.
G. The figure determined from the calculation
of item F must be increased by one-half of the percentage amount of the average
system line losses as shown on schedule B.
H. The annual dollar per kilowatt figure, as
calculated in accordance with item G, must be divided by the annual number of
hours in the on-peak period as specified in schedule A. The resulting figure is
the utility's net annual on-peak avoided capacity cost in dollars per
kilowatt-hour.
I. The annual dollar
per kilowatt figure resulting from the calculation specified in item G must be
divided by the total number of hours in the year. The resulting figure is the
utility's net annual avoided capacity cost in dollars per kilowatt-hour
averaged over all hours.
Subp.
6.
Net annual avoided capacity cost.
If the utility has no planned generating facility additions
for the ensuing ten years, but has planned additional capacity purchases, other
than from qualifying facilities, during the ensuing ten years, schedule B must
contain its net annual avoided capacity cost stated in dollars per
kilowatt-hour averaged over the on-peak hours and the utility's net annual
avoided capacity costs stated in dollars per kilowatt-hour averaged over all
hours. These must be calculated as follows in items A and B:
A. The annual capacity purchase amount, in
dollars per kilowatt, for the utility's next planned capacity purchase, other
than from a qualifying facility, must be discounted to present value as of the
midpoint of the reporting year, from the year of the planned capacity purchase.
The discount rate used must be the incremental cost of capital.
B. The net annual avoided capacity cost must
be computed by applying the figure determined in item A to the steps enumerated
in subpart
5, items D to I, excluding
item F.
Subp. 7.
Avoidable capacity costs.
If the utility has neither planned generating facility
additions nor planned additional capacity purchases, other than from qualifying
facilities, during the ensuing ten years, the utility must be deemed to have no
avoidable capacity costs.
Statutory Authority: MS s
216A.05;
216B.08;
216B.164
