(a) For forecast and historic data on deliveries, natural gas supply requirements and prices:

1. (1) By utility service area and statewide if available, the estimated monthly and annual in-state natural gas deliveries, winter season deliveries and peak day deliveries by end-use or customer classifications (in tabular and graphic files, in formats deemed appropriate by the board), specifically identifying the extent to which energy efficiency measures, fuel switching, and the sale of natural gas directly to end-users has been incorporated within such forecasts. Natural gas data may be requested for the categories stated below:

   1. (i) firm demand, specifying total residential deliveries, total commercial deliveries, total industrial deliveries, total electric generation deliveries, total natural gas vehicle sales, total out-of-state sales, total public authority deliveries other deliveries, and lost and unaccounted for natural gas;
   2. (ii) interruptible demand, specifying total residential deliveries, total commercial deliveries, total industrial deliveries, total electric generation deliveries, total natural gas vehicle sales, total out-of-state sales, total public authority deliveries, other deliveries, and lost and unaccounted for natural gas;
   3. (iii) transportation customer deliveries, specifying total residential deliveries, total commercial deliveries, total industrial deliveries, total electric generation deliveries, total public authority deliveries, and other deliveries;
   4. (iv) deliveries for injection and liquefaction requirements; and
   5. (v) the average monthly number of customers by the customer classes in total residential volumes, total commercial volumes, total industrial volumes, total electric generation volumes, total natural gas vehicle volumes, total out-of-state volumes, total public authority volumes, other volumes, and, if applicable, lost and unaccounted for natural gas.
2. (2) A forecast of natural gas supply requirements over the planning period, statewide and by utility service area, specifically identifying the amounts of natural gas needed to meet severe weather conditions, lost and unaccounted for natural gas, out-of-state sales commitments and use within the State. This information should be provided for peak day, winter season, and annual load, both for normal weather and design weather.
3. (3) 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 natural gas, the bases for such projections, and conversions to natural gas from other supply sources and expansion of distribution. The description shall include the source of the weather data, including years of data used, and a description of the calculation of peak day load.
4. (4) End-user and city gate natural gas prices by monthly and annual sales, a projection of estimated end-user and city gate natural gas prices for the planning period; and a description of the methodology and assumptions used to develop the foregoing projection of estimated prices.
5. (5) A detailed description of the methodology and assumptions used to develop the projection of estimated prices.

(b) For natural gas inventory and supply assessment:

1. (1) Projected supplies of natural gas by monthly and annual sendout, for each of the categories identified below:

   1. (i) total firm supply and capacity, including monthly (if applicable), annual and seasonal, storage, and other;
   2. (ii) total interruptible supply and capacity, including released firm transportation and interruptible transportation;
   3. (iii) total company sources, including LNG, liquefied petroleum gas/air (including propane), and other;
   4. (iv) total transportation of customer natural gas, including firm and interruptible; and
   5. (v) total appropriate deductions.

2. (2) An inventory of:

   1. (i) all existing supply sources, storage facilities, and transmission facilities used to provide service within the State;
   2. (ii) transmission and storage facilities under construction which would be used to provide service within the State, including their costs (projected or actual, where known) and capacities;
   3. (iii) transmission facilities proposed to be constructed, listing separately those with FERC approval, those in the FERC filing and pre-filing process, those which have sought non-binding precedent agreements; and
   4. (iv) transmission facilities operated, or planned to be operated by other than members of the Northeast Gas Association, to the extent that such information is available.
3. (3) An assessment of the ability of existing natural gas supply resources and transportation capacity, and those reasonably certain to be available, to satisfy their projected requirements over the planning period.
4. (4) A statement of recommended supply additions and demand-reducing measures for satisfying the natural gas supply requirements not reasonably certain to be met by natural gas supply sources identified in this section and the reasons therefore.

(c) For in-state natural gas production:

1. (1) a summary of monthly and annual natural gas production, including: number and location of wells, volume and energy content of annual production (million British Thermal Units [MMBTU] or dekatherms);
2. (2) summary of end-use or interconnection with local distribution, intrastate or interstate natural gas pipelines (if applicable);
3. (3) the number and demand of customers directly attached to local production and information on the reliability of that supply to those customers;
4. (4) amount of fuels/electricity used in production process (e.g., drilling; pumping; transportation of equipment, water, building materials, fluids, wastes; equipment use; waste treatment);
5. (5) amounts and concentrations of compounds used in production process;
6. (6) amount of land cleared associated with production process;
7. (7) and such other information as the chair, from time to time, may require to carry out the purposes of this Chapter.

(d) For interstate and intrastate natural gas pipelines:

1. (1) current certificated pipeline capacity entering and exiting the State of New York;
2. (2) a description of expansion pipeline capacity projects to serve New York customers, which have been approved but not yet constructed, and proposed projects awaiting approval;
3. (3) a list of contract quantities and deliveries to customers in the State of New York, including deliveries made directly to end-users, such as cogeneration facilities. Where available, such data shall be provided on a monthly and a contract year basis (November 1st through October 31st);
4. (4) a discussion of impediments to further market expansion in the State and the northeast region;
5. (5) peak load and capacity spatially referenced data, in a format that the board deems appropriate, of the existing pipeline facilities under current and projected load graphically identifying pipelines that are near or projected to exceed pipeline capacity during the planning period.

(f) For natural gas research and development:

1. (1) a statement of research and development plans, including objectives and programs in the areas of energy efficiency, dual fuel, and new energy technologies;
2. (2) recent results of such programs undertaken or funded to date; and
3. (3) an assessment of the potential impacts of such results.