Under the name of its operating electric utility, list all generating plants (1) within the respondent's balancing authority area which are controlled, metered or for which the required information is otherwise available to balancing authority area operators and (2) dynamically scheduled plants or units outside the balancing authority area. Specifically identify dynamically scheduled plants. Report only plant totals with generators in an operating or standby status. Provide totals for columns (d) and (e) as a last line. The total in column (d) should equal the value in column (c) on Schedule 2 for the month of the annual peak demand. The total in column (e) should equal the value in column (f) on Schedule 3 for the month of the annual peak demand. Any differences must be explained in a footnote. Refer to the Form 714 instructions for specific guidelines.

The peak demand and other terms used in this schedule are defined in the Form 714 instructions. Please first read the instructions, then complete this Schedule. The value in column (c) for the month of the annual peak demand should equal the total in column (d) in Schedule 1. Any difference must be explained in a footnote.

Enter the monthly "Net Energy for Load" which is the amount of energy that the balancing authority area requires internally including balancing authority area losses. The total in column (d) should equal the difference in the totals for columns (e) minus (f) on Schedule 5. The value in column (f) for the month of the annual peak demand should equal the total in column (e) in Schedule 1. Any differences must be explained in a footnote. Refer to the Form 714 instructions for specific guidelines.

Identify on this schedule: each balancing authority area with which the respondent balancing authority area has actual or scheduled interchange of energy, in column (b); the total annual megawatthours (MWh) of the scheduled interchange that were received by the respondent balancing authority area through all interconnection points with each balancing authority area, in column (c); the MWh of scheduled interchange delivered to each balancing authority area, in column (d); the MWh of total annual actual interchange received and delivered within each adjacent balancing authority area, in columns (e) and (f). Provide totals for columns (c), (d), (e) and (f). The difference in the totals for columns (e) minus (f) should equal the total in column (d) on Schedule 3. Any difference must be explained in a footnote. Refer to the Form 714 instructions for specific guidelines.

Identify on this schedule: each balancing authority area with which the respondent balancing authority area has actual or scheduled interchange of energy, in column (b); the total annual megawatthours (MWh) of the scheduled interchange that were received by the respondent balancing authority area through all interconnection points with each balancing authority area, in column (c); the MWh of scheduled interchange delivered to each balancing authority area, in column (d); the MWh of total annual actual interchange received and delivered within each adjacent balancing authority area, in columns (e) and (f). Provide totals for columns (c), (d), (e) and (f). The difference in the totals for columns (e) minus (f) should equal the total in column (d) on Schedule 3. Any difference must be explained in a footnote. Refer to the Form 714 instructions for specific guidelines.

For balancing authority areas where demand following is primarily performed by thermal generating units, the system lambda is derived from the economic dispatch function associated with automatic generation control performed at the controlling utility or pool control center. Excluding transmission losses, the fuel cost ($/hr) for a set of on-line and loaded thermal generating units (steam and gas turbines) is minimum 1/ when each unit is loaded and operating at the same incremental fuel cost ($/MWh) 2/ with the sum of the unit loadings (MW) equal to the system demand plus the net of interchange with other Balancing Authority Areas. This single incremental cost of energy is the system lambda. System lambdas are likely recalculated many times in one clock hour. However, the indicated system lambda occurring on each clock hour would be sufficient for reporting purposes. Respondents must provide the following data: the system lambda, in dollars, for each hour of the year starting with 1 a.m. January 1 as more fully described in the Form 714 instructions. In column (b) indicate the time zone and the days for which daylight savings time was observed. This schedule will have 365 rows for the report year (366 rows for a leap year).

Provide, as a footnote, an explanation describing the reason for the unavailability of system lambda information. The Commission expects that all Energy Management Systems, with proper instructions, can record the system lambda being used for economic dispatch of the balancing authority area's thermal units.

Respondents should be able to report system lambda, along with the other information reported on a Balancing Authority Area basis, that describe the operation of such areas from information that should be readily available. The Commission is not requesting Respondents to develop incremental or marginal cost (either short or long term) according to any formula. Nor is the Commission requesting "avoided cost rates" that electric utilities file with state commissions or otherwise make available for prospective qualified facilities.

Enter the name of each entity, including the respondent, that forms the planning area for which this report is being prepared and their coincident summer and winter peak demands in megawatts. Refer to the Form 714 instructions for specific guidelines.

Respondents must provide the following data: the planning area's actual hourly demand, in megawatts, for each hour of the year starting with 1 a.m. January 1 as more fully described in the Form 714 instructions. In column (b) indicate the time zone and the days for which daylight savings time was observed. This schedule will have 365 rows for the report year (366 rows for a leap year). For hours when this information is not available, enter "0.00" and provide, as a footnote to those hours, an explanation describing the reason for the unavailability of the data.

Provide the planning area's forecast summer and winter peak demand, in megawatts, and annual net energy for load, in megawatthours, for the next ten years.