Topic:"Energy Efficiency Financing" in M04265

Other ECONOMIC DEVELOPMENT QUESTIONNAIRE Section A: Economic Development/Incentive Rates - discounted utility rates offered for, a) significant load additions by existing customers, and/or b) load additions created by customers new to the...

AI summary The questionnaire asks whether utilities are allowed to offer economic development/incentive rates, including the types of utilities, rate mechanisms, load applicability, cost considerations, and how impacts are tracked. It also explores how such rates are treated during rate cases and the considerations used to justify them.

General Description PROSCREEN Il's advantage as an integrated planning system is its strength in all functional areas of utility planning. PROSCREEN Il allows analysts to address all aspectS of an integrated planning study at the depth and...

AI summary PROSCREEN II is an integrated utility planning system that offers comprehensive capabilities in demand and supply-side resource optimization, financial analysis, and production cost simulation. It is connected to EMA's PROMOD III system, allowing for seamless data integration and analysis of financial implications.

Introduction The PROVIEW (PRY) Module is a resource planning model which determines the least-cost balanced demand and supply plan for a utility system under prescribed sets of constraints and assumptions. PROVIEW incorporates a wide varie...

AI summary The PROVIEW module is a resource planning tool used to develop least-cost balanced demand and supply plans for utility systems. It works with other modules like GAF and LFA to evaluate DSM programs through screening, optimization, and detailed analysis, incorporating factors such as emissions, cost effectiveness, and reliability.

Table UARB-IR-33-B Supplier A Supplier B Supplier C Supplier D Supplier E Off System Purchases A verage/Incr A verage/Incr A verage/lncr A verage/Incr A verage/Incr A verage/Incr ($/Mwh) ($/Mwh) ($/Mwh) ($/Mwh) ($/Mwh) ($/Mwh) 1993 $59.60...

AI summary The table provides average and incremental costs per MWh for various suppliers and off-system purchases from 1993 to 1998. The text mentions that existing power purchase contracts are being filed confidentially and that no future contracts are currently under negotiation with NSPI.

RESPONSE TO INFORMATION REQUEST TO: CAPE BRETON REGIONAL MUNICIPALITY FROM: NSPI Question IR-1: Please provide a description of the existing sources of energy used by NSPI to produce electricity in Nova Scotia. What amount of energy is use...

AI summary NSPI responds to a request for information about its energy sources by referring to statistics from its 1998 Annual Report, specifically page 19, which includes details on energy production from various sources, including wind turbines.

"REVISED" Question 7: Reference 3) 1998 Nova Scotia Power Annual Report, page 16: ^^Nova Scotia is building its electric utility business to become more competitive. In July, the National Energy Board approved the company's export license....

AI summary The document contains a revised question from a regulatory proceeding regarding Nova Scotia Power's export sales, customer load retention, and financial statements. It asks whether NSPI explored replacing lost customer loads through exports, provides details on 1999 export sales, requests financial statements, and inquires about shutting down uneconomic generating facilities.

Project $ millions Timeframe SOEP Phase I 2,000 1997-1999 SOEP Phase II 1,000 2002-2004 M&NPP 335 1999-2000 NS Distribution System 465 2000-2007 NSPI 230 2000-2004 Total $4,030 On-going offshore exploration and other projects arising from...

AI summary The document outlines several major energy projects in Nova Scotia with their associated costs and timeframes, including the Sable Offshore Energy Project (SOEP) and the NS Distribution System. It also estimates that ongoing offshore exploration and related developments could add $300-400 million to the total project costs over the next decade.

RECOMMEND A TIO NS - 1. In light of the on-going weakness of the CBRM economy and the implications of the closure of CBDC, a framework for ensuring the CBRM gains early access to natural gas should be given careful consideration by governm...

AI summary The recommendations focus on addressing economic challenges in the CBRM due to CBDC's closure, promoting participation in offshore energy projects, developing training programs for natural gas jobs, and reviewing provincial energy policy to better align with supply and demand conditions.

2. FACTORS AFFECTING NATURAL GAS DEMAND It is important to note that the mere availability of natural gas in Nova Scotia does not in itself guarantee a market. It must compete with existing fuels whose suppliers, including CBDC, would like...

AI summary The availability of natural gas in Nova Scotia does not ensure market success, as it must compete with existing fuels like those supplied by CBDC. Factors influencing natural gas demand include inter-fuel economics, gas distribution policies, environmental considerations, CBDC production capabilities, and potential electricity deregulation.

Based on the favourable relative energy price assumptions outlined above, natural gas demand rises from about 8.1 million MMBtu in 2000 (average of 22,000 MMBtu/day) to 20.2 million MMBtu in 2010 (58,350 MMBtu/day). Expenditures on gas ris...

AI summary Natural gas demand in Nova Scotia is projected to increase significantly from 2000 to 2010, with corresponding rises in expenditures. Incentive programs promoting the conversion to natural gas are detailed in Appendix E.

Demand and Expenditures Consumers and businesses in the CBRM spend about $140 million annually on energy in final demand applications for which there is at least some potential for conversion to natural gas. Energy use and expenditures est...

AI summary Consumers and businesses in the CBRM spend approximately $140 million annually on energy for final demand applications that could potentially convert to natural gas. Sector-specific energy use and expenditure estimates by fuel type are detailed in Table IV-6.

Table IV-6 CBRM Energy Expenditures by Sector and Fuel Type, 1996 (1) ($ millions) Residential Comm Indi Industrial million mmbtu $ million million mmbtu $ million million mmbtu $ million #2 oil 2.41 21.1 .91 5.0 .27 1.5 #6 oil - - .20 .6...

AI summary Table IV-6 presents energy expenditures in CBRM by sector and fuel type in 1996, showing data for residential, commercial, and industrial sectors. The table includes expenditures in million mmbtu and $ million for various fuels such as #2 oil, #6 oil, propane, electricity, and wood. Industrial data is sourced from SYSCO and CBDC.

Review Board. Though the targets set out in the policy indicate that the CBRM should gain access, there is no stipulation as to timing other than required access should be achieved within seven years. A seven-year wait may be too long for...

AI summary The text recommends early gas access for CBRM to improve economic competitiveness and suggests initiatives to pool resources for offshore projects and develop training programs for natural gas distribution jobs. These measures aim to support local businesses and workforce readiness.

TOTAL ENERGY EXPENDITURES ($ 000s) I Electricity Petroleum Wood Natural Gas Total LFO HFO Propane - Andrews 1996 103,625 27,507 4,059 4,136 213 0 139,541 1997 108,623 27,920 4,120 4,199 213 0 145,075 1998 108,091 28,339 4,182 4,261 213 0 1...

AI summary The table presents total energy expenditures from 1996 to 2010, categorized by energy type and year. It includes expenditures on electricity, petroleum, wood, and natural gas. The electricity price is also provided as $23.45/mmbtu.

3. CONVERSION COST REDUCTION MEASURES The key problem to be overcome at the individual consumer level in converting to natural gas is the high capital cost of conversion and retrofit of space heating systems in residential dwellings. These...

AI summary The text discusses the high capital costs of converting residential heating systems to natural gas and highlights the need for financial assistance such as loans or grants to overcome this barrier. It notes that without such support, the savings from lower natural gas prices may not justify the initial investment.

Household Conversion Cost These costs are normally those incurred within the house to convert both the energy consuming equipment to natural gas and to modify or replace the space heating delivery system throughout the house (re-ducting)....

AI summary The text discusses the costs associated with converting household energy systems from other fuels to natural gas, including equipment replacement and ducting modifications. It outlines various methods to offset these costs, such as government grants, utility-backed loans, and equipment subsidies.

ATTACHMENT "A" This attachment outlines procedures by which the requirements of Availability Clause (1) and Special Condition (1) are to be satisfied. - (1) The customer shall apply in writing to take service under this rate, outlining the...

AI summary This attachment outlines procedures for customers to apply for service under a load retention rate, including initial screening, determination of load retention price, and adjudication by the UARB if needed. It also details economic and technical feasibility criteria and the impact on NSPI's other customers.

- 8. Schedule SUS is a non-cost based incentive rate available to any LPS and LIS customer with a minimum process steam requirement of 10,000 pounds per hour or the thermal energy equivalent thereof. - 9. Schedule SUS is designed to provid...

AI summary Schedule SUS is a non-cost based incentive rate designed to encourage industrial customers to remain on GSU's system by offering competitive pricing for power, reducing the incentive to cogenerate. CSU has experienced significant load loss to cogeneration and anticipates further losses, but intends for any revenue loss from Schedule SUS to be borne by shareholders, not recovered in future rate proceedings.