Independent System Operator (CAISO). They also monitor the real time operations within PacificGas and Electric Company’s electric transmission system. Outage Coordination group manages and coordinates all transmission equipment outages for scheduled maintenance, construction and modification or testing of all transmission equipment on 60, 70, 115, 230 and 500 kV systems. It coordinates their activities with BPA, WAPA, MID, DCWR, SMUD, SCE, Sierra Pacific, PP&L, BART, TID, CCSF, NCPA, SVP and other agencies and ECCO. It also provides a single point of contact for outage coordination with the CAISO. Grid Control Centers are responsible for monitoring and directing transmission operations in their geographic regions. These centers coordinate switching for planned and emergency events and work closely with the Real Time Operations.
The Report presents an analysis of the authorized revenue requirements and cost analyses for the four California investor-owned utilities: PacificGas & Electric (PG&E), Southern California Edison (SCE), San Diego Gas & Electric (SDG&E) and Southern California GasCompany (SoCal Gas). “Authorized revenue requirements” are the amounts of revenues that the utilities are authorized to collect from customers. Using sales forecasts, the rates are set to collect the authorized revenue requirement. To the extent that actual sales end up being different from forecasted sales, the utilities may end up collecting more or less than the authorized revenue requirements. Discrepancies between authorized revenue requirements and actual revenues and expenses are captured through balancing account mechanisms, which “true-up” the actual
CERCLA Matters: The federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 (CERCLA) and its amendments or state equivalents impose joint and several strict liabilities, regardless of fault, upon generators of hazardous substances resulting in removal and remediation costs and environmental damages. Liabilities under these laws can be material and in some instances may be imposed without regard to fault or for past acts that may have been lawful at the time they occurred. Of the 10 sites, 4 sites are superfund sites under CERCLA for which the Company has been notified that it is a potentially responsible party but for which the site assessment and remediation are not being managed by the Company. As of December 31, 2013, a liability of $0.3 million accrued on these sites represents management's best estimate of its potential remediation costs with respect to these superfund sites.
The FERC has jurisdiction with respect to ensuring the reliability of electric transmission service, including transmission facilities owned by utilities within ERCOT. The FERC has designated the NERC to establish and enforce reliability standards, under FERC oversight, for all owners, operators and users of the bulk power system. The FERC has approved the delegation by NERC of compliance and enforcement authority for reliability in the ERCOT region to the TRE. To maintain compliance with the mandatory reliability standards, we may be subjected to higher operating costs and/or increased capital expenditures. While we expect to recover costs and expenditures from customers through regulated rates, there can be no assurance that the PUCT will approve full recovery of such costs or the timing of any such recovery. In addition, if we were to be found to be in noncompliance with applicable reliability standards, we could be subject to sanctions, including monetary penalties. Under the Energy Policy Act of 2005, FERC can impose penalties (up to $1 million per day per violation) for failure to comply with reliability standards, which would not be recoverable from customers through regulated rates. We have five registrations with NERC – as a transmission planner, a transmission owner, a transmission operator, a distribution provider and a load serving entity. As a registered entity, we are subject to periodic audits by the TRE of our compliance with reliability standards. These audits will occur as designated by the TRE at a minimum of every three years. We cannot predict the outcome of any such audits.
Indianapolis GasCompany (a product of an 1890 merger between Indianapolis Gas Light & Coke and its subsidiary and two smaller gas companies). Citizens Gas was selling gas at the lowest rate in the nation. Public opposition to a rate increase by Citizens Gas in 1921, which had been approved by the state’s public service commission, prompted the company to surrender its charter. In 1929, however, the city of Indianapolis announced its intention to exercise its ownership option under the 1905 franchise charter. Angry stockholders launched a lawsuit to prevent the takeover. The suit was resolved by a federal judge in the city’s favor in 1930, and a subsequent appeal in 1931 upheld the earlier decision. The city faced a second obstacle: in the heart of the Great Depression, it could not raise the money required to accomplish the transfer. The city requested a $9 million loan from the Public Works Administration (PWA), a creation of Franklin D. Roosevelt’s New Deal. Although administrators at the PWA (and, later, the Works Progress Administration) were sympathetic, they doubted their authority to give the loan, and the city’s requests languished. The city was not able to find an acceptable bid for its bonds until 1935, when it accepted the offers from Otis & Company of Cleveland and Halsey Stuart & Company of Chicago. That year ownership of the company was transferred to the city, and it was rechristened Citizens Gas & Coke Utility. The gascompany remained, however, a charitable trust rather than a municipal department.
The Prince Rupert Gas Transmission project will supply natural gas to a proposed Pacific NorthWest LNG conversion facility near Prince Rupert. The gas will travel some 900 kilometres from the North Montney gas fields near Hudson’s Hope. Another TransCanada project, Coastal GasLink, will supply natural gas from a point near Dawson Creek to a proposed LNG facility near Kitimat.
During summer periods, when electric demand at a power station is high due to the amount of air conditioners, lights, equipment, etc. being used within the region, demand charges go up to offset the utility’s cost of providing enough electricity at that given time. Photovoltaic systems not only offset the amount of electricity usage for a building but also reduce the building’s electric demand from the utility, resulting in a higher cost savings as well. As shown in the cost analysis for a 20 kW PV system below, installation of this system is not cost-effective. Please note, roof replacement should be undertaken prior to installation of a roof-mounted PV system.
The electric geyser used is a 150 Liter geyser manufactured locally. It consists of a 3 kilo Watt electric element and standard thermostat which comes supplied standard with the unit. The electric geyser will have no timers, geyser controllers or electric blankets to assist the geyser. It will be connected to the mains supply 24 hours a day, 7 days a week to simulate an average household’s hot water geyser.
Any person who, knowingly and with intent to defraud an insurance company or other person, files an Application or insurance containing any false information, or conceals for the purpose of misleading, information concerning any material fact thereto, commits a fraudulent insurance act, which is a crime.
(3) The arbitrators shall determine the questions in dispute between the parties to the arbitration and shall decide as to the necessity or propriety of conducting any of the pipes, wires or conductors or carrying any of the works of the company through the land of the other party if that party objects to it being done. (4) If the decision is in favour of the company or if no such objection is made, the arbitrators shall adjudge the sum of money that is to be paid to the owner of the property to be taken or used for those purposes, or any of them.
8. Indemnification. Interconnecting Customer and Company shall each indemnify, defend and hold the other, its directors, officers, employees and agents (including, but not limited to, Affiliates and contractors and their employees), harmless from and against all liabilities, damages, losses, penalties, claims, demands, suits and proceedings of any nature whatsoever for personal injury (including death) or property damages to unaffiliated third parties that arise out of, or are in any manner connected with, the performance of this Agreement by that party, except to the extent that such injury or damages to unaffiliated third parties may be attributable to the negligence or willful misconduct of the party seeking indemnification.
This report contains forward-looking statements that relate to future transactions, events or expectations. RGC Resources, Inc. (“Resources” or the “Company”) may publish forward-looking statements relating to such matters as anticipated financial performance, business prospects, technological developments, new products, research and development activities and similar matters. These statements are based on management’s current expectations and information available at the time of such statements and are believed to be reasonable and are made in good faith. The Private Securities Litigation Reform Act of 1995 provides a safe harbor for forward-looking statements. In order to comply with the terms of the safe harbor, the Company notes that a variety of factors could cause the Company’s actual results and experience to differ materially from the anticipated results or expectations expressed in the Company’s forward-looking statements. The risks and uncertainties that may affect the operations, performance, development and results of the Company’s business include, but are not limited to, those set forth in the following discussion and within Item 1A “Risk Factors” of this Annual Report on Form 10-K. All of these factors are difficult to predict and many are beyond the Company’s control. Accordingly, while the Company believes its forward-looking statements to be
b. Two or more service connections of the same characteristics where required for a single customer by reason of the size of the load (such as a lighting load in excess of the capacity of one phase distribution) or by reason of the character of the load (such as welders where a combination on the same service with lighting is impracticable). Note: All electric facility installation, lines, and equipment, must conform to the latest edition of the BGE Gas & Electric Metering Manual available under the New Construction Services section on bge.com
The authority requested of DOE by CG&E is a necessary condition for exporting under section 202(e) of the FPA. CG&E must make the necessary commercial arrangements, including obtaining all necessary transmission access required to wheel the exported energy to the foreign purchaser, and obtain any and all other regulatory approvals which may be required in order to effect the export. In considering CG&E’s request for service, the transmitting utilities would have to assess the electric reliability impacts of moving the export through their system and,