Economic and financial terms
Process by which the cost of fixed assets is spread over a certain period to the advantage of the Company, usually the useful life of the asset.
Net cash flow from operations is represented by the cash generated by a company over a certain period of time. Specifically, the difference between current inflows (mainly cash revenue) and current cash outflows (costs in the period that generated cash outflows).
Includes both net income for the period and changes in equity, which are recognised in equity in accordance with IFRSs (Other components of comprehensive income).
Fixed operating costs of regulated activities, represented by the sum of “Total recurring personnel expense” and “Recurring external operating costs”.
Income from selling goods and/or providing services that are integral to the core business, including all recurring economic values linked to a company’s typical field of business.
A financial instrument is defined as a derivative when its price/yield profile derives from the price/yield parameters of other major instruments – known as “underlying” – such as commodities, currencies, interest rates, securities and share indices.
Payment to shareholders voted for by the Shareholders’ Meeting and proposed by the Board of Directors.
Ratio between the dividend and net profit for the period, and equal to the percentage of profits paid out to shareholders in the form of dividends.
Difference in a given period between sales and services revenues, other revenues, operating costs, amortisation, depreciation and impairment losses over a given period. It is therefore the operating profit before financial revenues and costs and taxes.
Used by Snam in its internal (business plan) and external (to analysts and investors) presentations. Unit of measurement to assess the Group’s operating performance, as a whole and in the individual business segments, in addition to EBIT. Determined by the difference between revenue and operating costs.
Indirect tax for immediate payment, applied to the production or consumption of certain industrial goods (including oil products and natural gas).
Costs incurred for the acquisition of long-term assets where the useful life does not expire over one reporting period.
A valid indicator of the ability to meet financial obligations. Net financial debt is represented by gross financial debt minus cash and cash equivalents as well as other financial receivables not held for operations.
Net cost incurred for using third-party capital. Includes other net expense related to financial operations.
Net investments of an operational nature, represented by the sum of net working capital and fixed assets, provisions for employee benefits and assets and liabilities held for sale.
EBIT minus the result from financial operations and income taxes.
Net working capital
Capital which is invested in short-term assets and is an indicator of a company’s short-term financial position. Calculated using all short-term, non-financial assets and liabilities.
Balance sheet item which shows long-lasting assets, net of amortisation, depreciation and impairment losses. These are divided into the following categories: “Property, plant and equipment”, “Compulsory inventories”, “Intangible assets”, “Equity investments”, “Financial assets” and “Other non-current assets”.
Costs incurred in carrying out a company’s core business. These include purchases, services, energy, consumables, maintenance and personnel expense.
Total resources contributed by shareholders, plus retained profits and minus losses.
NATURAL GAS TRANSPORTATION AND REGASIFICATION
Document governing the rights and obligations of those involved in providing the transportation service.
This is the physical network point, or local combination of physical points, at which the transporter redelivers gas transported to the user, and where such gas is metered.
Document which sets out the rules and processes characteristic of the natural gas regasification service.
Unit prices applied for regasification. These include capacity and commodity tariffs, related to the required regasification capacity by users and to the volumes of gas unloaded from tankers, respectively.
Period of time (usually four years) for which criteria are defined for setting tariffs for transporting and dispatching natural gas and for regasifying liquefied natural gas. For the transportation business, the third regulatory period is under way, which began on 1 January 2010 and will end on 31 December 2013. For the regasification business, the third regulatory period is under way, which began on 1 October 2008 and will end on 31 December 2013, following an extension of the tariff criteria for the transition period from 1 October 2012 to 31 December 2013.
Period of time into which the regulatory period is divided. Since 1 January 2010, transportation tariffs have referred to the calendar year (1 January to 31 December). For LNG regasification, the last thermal year, which began on 1 October 2011 and will end on 31 December 2013, has had a one-off extension of 15 months for tariff purposes from 1 October 2012 to 31 December 2013.
Transportation capacity is the maximum quantity of gas which can be injected into the system (or withdrawn from it) during the course of a gas day, at a specific location, in compliance with the technical and operating restrictions established for each section of pipeline and the maximum performance of plants located along such pipelines.
These capacities are assessed using hydraulic network simulations carried out in appropriate transportation scenarios and in accordance with recognised technical standards.
Unit prices applied for transporting and dispatching natural gas. These include capacity and commodity tariffs, related to the required transportation capacity by users and to the volumes of gas injected into the network, respectively.
The user of the gas system, which, by confirming the capacity granted, acquires transportation capacity for its own use or assignment to others.
A virtual point located between the Points of Entry and Points of Exit of the national gas transportation network where users and other authorised parties may, on a daily basis, exchange and sell gas injected into the network.
Liquefied natural gas (LNG)
Natural gas essentially comprising methane liquefied by cooling at around -160°C, at atmospheric pressure, to make it suitable for methane tanker transportation or reservoir storage. In order to be injected into the transportation network, the liquid must be reconverted into a gas at regasification plants and brought to the operating pressure of the pipelines.
Industrial process whereby natural gas is converted from a liquid to a gaseous state.
This consists of the gas pipelines indicated in Article 2 of the Ministerial Decree of 22 December 2000, as updated annually. It is the aggregate of gas pipelines and plants which have been assessed and checked taking into account restrictions imposed by imports, exports, key national production and storage facilities, and is used to transfer significant quantities of gas from these network injection points to major areas of consumption. Several inter-regional gas pipelines as well as smaller pipelines which serve to close network links formed by the above pipelines are also included for the same purpose. The national transportation network also includes compression stations and plants connected to the pipelines described above.
Hydrocarbon mixture consisting mainly of methane, and to a lesser degree, ethane, propane and higher hydrocarbons. Natural gas injected into the gas pipeline network must comply with a single quality specification to ensure that the gas in transit is interchangeable.
Natural gas transportation network
The aggregate of gas pipelines, line plants, compression stations and infrastructure, which, at the national and regional level, provide the transportation of gas by interconnecting with international transportation networks, production and storage points and redelivery points for the purposes of distribution and use.
This consists of gas pipelines not included in the list in Article 2 of the Ministerial Decree of 22 December 2000, as updated annually, and its main function is to move and distribute gas in demarcated local areas, which are typically regional in scale.
NATURAL GAS STORAGE
Period from 1 April to 31 October of the same year.
Period of time (usually four years) for which criteria are defined for setting tariffs for the natural gas storage service. We are currently in the third regulatory period, which runs from 1 January 2011 to 31 December 2014.
Period of time into which the regulatory period is divided. Since 1 January 2011, storage tariffs have been based on the calendar year (1 January to 31 December).
Period from 1 November of one year to 31 March of the following year.
Mining storage is necessary for technical and economic reasons in order to enable optimum cultivation of Italy’s gas natural reservoirs.
Aims to respond to changing hourly, daily and seasonal demands.
Aims to provide for a lack of or reduction in supplies from non-EU imports or crises in the gas system.
NATURAL GAS DISTRIBUTION
The deed by which a local authority entrusts to a company the management of a service which falls within the remit of said authority and for which said company assumes the operational risk.
The document governing the rights and obligations of those involved in providing the gas distribution service.
Consumer who buys gas for their own use.
Gas distribution service
Service of transporting natural gas through networks of local pipelines from one or more delivery points to redelivery points, generally at low pressure and in urban areas, for delivery to end customers.
This is the point of demarcation between the gas distribution plant and the plant owned or managed by the end customer at which the distribution company redelivers gas transported for supply to the end customer, and at which metering occurs.