Exhibit 99.305



DUC CALCULATIONS

DEFINITION OF PROBLEM
The right on the paths (branch groups) that are congested are allocated to the
SCs based on the value that the SC assigns to the path. Each SC specify the
path's worth implicitly through the adjustment bids which are submitted across
the path. However, it is not necessary nor always possible for a SC to submit
adjustment bid for all its schedules.

When congestion occurs on a path, the path's congestion is removed by adjusting
the schedule of the SC(s) that have assigned lower value on the path. If the
congestion is removed by modifying the schedules within the adjustment curves
submitted by the SCs, then the usage charge of the congested path is set to the
value that the marginal SC had specified for the path. However, if there are not
sufficient adjustment curves or not sufficient range in the adjustment curves,
then the path congestion could not be resolved. In order to ensure that the path
congestion can always be removed, default adjustment curves are created for the
schedules that do not have any adjustment curve and default segments are added
to extend the adjustment curves that are submitted by the SCs. In this document,
the default adjustment curves and default extension segments are referred to as
non-economical region.

The default prices (priority) assigned to the non-economical region can be
grouped into two categories, i) Incremental segment; ii) Decremental segment.
Different priority level could be assigned to the default segments and depending
on the schedule several default segments can be added to a schedule. For
example, a generator which is scheduled at 100 MW with no adjustment curve in
the hour-ahead market and which has the physical limit of (0,300) MW and the
final day ahead schedule of 200 MW will have the following default adjustment
curve :

(0 MW, -4000.0 $/MWh) (100 MW, -4000.0 $/MWh)
(100 MW, 600.0 $/MWh) (200 MW, 600.0 $/MWh)
(200 MW, 4000.0 $/MWh) (300 MW, 4000.0 $/MWh)
(300 MW, 30,000 $/MWH) (10000 MW, 30,000 $/MWh)

After the current optimization process, if the schedule is moved to the
non-economical region, then a process has to be put in place to reduce the
penalty prices assigned to the default segments as much as possible without
effecting the optimality of the primal solution (i.e. final schedules), i.e. the
current optimization process should be used to obtain the schedules and the
second process should be used to determine the transmission prices. In
determining the transmission prices, the second process should also have the
capability of adding a sur-charge to the transmission price, and limiting the
transmission price with a lower and upper bound.

The problem can be summarized as follows, in case of non-economical dispatch,
the transmission usage charge for the paths which were impacted by the
non-economical dispatch should be set to a value greater than or equal to the
last economical value given





to the path and this charge should be set such that it is consistent with the
marginal-cost-based pricing of energy and transmission capacity.