(a) For generation units that are connected to the grid within the New York control area, the following operating and unit characteristics:

1. (1) station and unit name and/or number;
2. (2) location (town, county, load zone and state);
3. (3) the principal owner of the unit;
4. (4) the contact person and/or organization, address, and phone number;
5. (5) type of unit and firing type (e.g., tangential);
6. (6) type of primary and alternate fuel(s);
7. (7) onsite or offsite company-owned or -leased maximum storage capacity for each fuel and for the generation unit;
8. (8) net capability (megawatt) for summer and winter capability periods, measured to the standard of the bulk system operator, if available;
9. (9) type of cooling system;
10. (10) the month and year in which the unit initially entered commercial service;
11. (11) anticipated retirement date, if any;
12. (12) the expiration date of Federal or State licenses, where applicable;
13. (13) average annual unit heat rate (Btu per kWh) while burning each different fuel type, and including an average heat rate for the year burning all fuels;
14. (14) the net electric energy generated (megawatt-hour) monthly by fuel type and the total annual net energy generation (megawatt-hour);
15. (15) unit availability (total hours, dates and times of operations) for electric generating;
16. (16) fuel consumption (in both physical units and Btu) by fuel type for each month, separately reported for the unit and any backup boiler;
17. (17) unit PTID, if available;
18. (18) unit co-generation status;
19. (19) nameplate rating of unit (megawatt);
20. (20) unit rerating information shall be presented, indicating the dates and capacities of all planned reratings, by unit;
21. (21) total tons of oxides of sulfur, oxides of nitrogen, carbon dioxide, and particulate matter released, if any;
22. (22) total pounds of mercury released, if any;
23. (23) emission rates for oxides of sulfur, oxides of nitrogen, carbon dioxide, particulate matter, and mercury in pounds per MMBTU of fuel consumed by the generating unit, if applicable;

24. (24) if applicable, once through cooling water usage, as follows:

    1. (i) if the water source is a river, such usage shall be measured as intake flow as annual average gallons per day and as a percent of river flow (based on minimum average seven consecutive day, 10-year flow); and
    2. (ii) if the water source is a lake or ocean, such usage shall be measured in gallons per year;

25. (25) if applicable, a tabular summary identifying each emission control measure for a particular pollutant currently installed on the unit or planned to be installed, including, for each control measure and pollutant, the associated:

    1. (i) control efficiency, including estimated pre-control and post-control emission rates (in lbs/MMBTU);
    2. (ii) installation date of emission control measure;
    3. (iii) remaining useful life of existing emission control measure;
    4. (iv) initial cost and annual operating expenditures associated with emission control measure; and
    5. (v) heat rate penalty;

26. (26) for natural gas-fired projects:

    1. (i) natural gas supply/transportation contract start and end dates; name of pipeline(s) and its delivery service terms, including the maximum daily deliveries, the number of days that the maximum daily deliveries is available during the year, whether firm or interruptible basis, and seasonal allocation, if any, name of supplier and the amount of natural gas consumed from in-state production, if known;
    2. (ii) local distribution company delivery service terms, including the maximum daily deliveries, the number of days that the maximum daily deliveries is available during the year, whether firm or interruptible basis, and seasonal allocation, if any; and
    3. (iii) natural gas consumption for natural gas received directly from interstate natural gas pipelines;

27. (27) for each generation unit which has obtained required Federal or State permits, but which has not commenced commercial operation, the following information in a tabular summary may be requested:

    1. (i) station and unit name and/or numbers;
    2. (ii) location (town, county and state);
    3. (iii) the contact person and/or organization, address and phone number;
    4. (iv) the principal owner of the station and unit;
    5. (v) type of unit;
    6. (vi) fuel type;
    7. (vii) resource size (MW);
    8. (viii) status of resource (e.g., under construction/development, under licensing/review);
    9. (ix) target in-service date; and
    10. (x) storage capacity for any fuels stored onsite.

(b) For electricity transmission and distribution companies within the New York control area:

1. (1) the number of customers, by rate class, BSO load zone, and technology type, that sell energy back to the electric transmission and distribution company (net meter), and the amount of net excess energy received for the year; and
2. (2) the average hourly load shape for the average customer in each rate or customer class, if available;

3. (3) a list of the characteristics and terminal points on all existing transmission facilities greater than or equal to 115 kilovolts, including:

   1. (i) terminal names (to and from);
   2. (ii) voltage (design and operating);
   3. (iii) circuit mileage;
   4. (iv) number of circuits;
   5. (v) type of conductor;
   6. (vi) summer and winter thermal rating of each circuit;
   7. (vii) principal structure; and
   8. (viii) circuit mileage for each type of structure, including the number of circuits on a common right-of-way;

4. (4) for each proposed transmission facility greater than or equal to 115 kilovolts:

   1. (i) identification of the terminals and a statement of the various factors, including environmental factors, that were considered in designating terminal locations;
   2. (ii) voltage (design and proposed operation);
   3. (iii) target in-service date;
   4. (iv) number of circuits;
   5. (v) approximate length in miles;
   6. (vi) type of construction;
   7. (vii) summer and winter thermal rating of each circuit;
   8. (viii) project description; and
   9. (ix) conductor size;

5. (5) forecast and historical data on electricity usage and demand, including:

   1. (i) long-term econometric and energy efficiency forecasts over the planning period for annual energy, NYCA coincident and non-coincident summer peak demand, and NYCA coincident and non-coincident winter peak demand;
   2. (ii) historical actual and weather-adjusted data over the planning period for annual energy, coincident and non-coincident summer peak demand, and NYCA coincident and non-coincident winter peak demand, including the date and time of the NYCA coincident and non-coincident summer and winter peak demands; and
   3. (iii) a detailed technical description of the forecast and weather-adjustment procedures used, including methodologies and assumptions;
6. (6) a load and capacity schedule for each capability period, indicating generation capacity additions reasonably certain to be available, retirements, and reratings;
7. (7) a capacity mix table by calendar year;

8. (8) a summary of changes occurring to the operating system since the last report submission, including:

   1. (i) new generating facilities added to the system;
   2. (ii) generating facilities retired from the system;
   3. (iii) significant reratings of units;
   4. (iv) significant transmission line additions, retirement or reratings that occurred;
9. (9) a summary table of changes to the planned resource systems and energy storage systems;

10. (10) a table containing an itemized list of reasonably certain resource additions indicating the following information, where applicable:

    1. (i) station/unit name;
    2. (ii) owner/operator name;
    3. (iii) unit type;
    4. (iv) fuel type;
    5. (v) name plate rating, and summer and winter capability (megawatt);
    6. (vi) status of resource (e.g., under construction/development, under licensing/review);
    7. (vii) projected operational date; and
    8. (viii) location (town, county, state and load zone);

11. (11) a table containing an itemized list of reasonably certain resource reratings indicating the following information, where applicable:

    1. (i) station/unit name, PTID;
    2. (ii) owner/operator name;
    3. (iii) unit type;
    4. (iv) fuel type;
    5. (v) current, incremental, and proposed total name plate rating, and summer and winter capability (megawatt);
    6. (vi) status of resource (e.g., under construction/development, under licensing/review);
    7. (vii) projected rerating date; and
    8. (viii) location (town, county, state and load zone);

12. (12) a table containing an itemized list of reasonably certain resource retirements indicating the following information, where applicable:

    1. (i) station/unit name, PTID;
    2. (ii) owner/operator name;
    3. (iii) unit type;
    4. (iv) fuel type;
    5. (v) name plate rating, and summer and winter capability (megawatt);
    6. (vi) reason for retirement;
    7. (vii) projected retirement date; and
    8. (viii) location (town, county, state and load zone);
13. (13) the location of each existing and proposed electric transmission facility that forms a significant part of the bulk power transmission system (150 kV and above);
14. (14) a simplified one-line system diagram of the existing and proposed electric transmission facilities that forms a significant part of the bulk power transmission system (150 kV and above);
15. (15) a description of the load forecasting methodology and the assumptions and data used in the preparation of the forecasts, specifically including projections of demographic and economic activity and such other factors, statewide and by service area, which may influence demand for electricity, the bases for such projections, and conversions to electricity from other supply sources and expansion of distribution;
16. (16) a projection of estimated electricity prices for the planning period; and a detailed description of the methodology and assumptions used to develop the projection of estimated prices;
17. (17) peak load and capacity spatially referenced data, in a format that the board deems appropriate, of the existing transmission facilities under current and projected load graphically identifying circuits that are near or projected to exceed ordinary line capacity during the planning period.

(c) For electricity research and development:

1. (1) a statement of research and development plans, including objectives and programs in the areas of energy efficiency, load management, electric generation and transmission, new energy technologies and pollution abatement and control;
2. (2) recent results of such programs undertaken or funded to date; and
3. (3) an assessment of the potential impacts of such results.

(d) The bulk system operator shall provide the following data on the markets it administers:

1. (1) the net electric energy generated monthly in megawatt-hours by fuel type and the total annual net energy generation in megawatt-hours for each unit participating in the BSO markets;
2. (2) revenues paid by service type (e.g., energy, capacity, ancillary services) to each unit participating in the BSO markets; and
3. (3) such information as the board may request to confirm or augment information supplied by major electricity suppliers.