{
  "url": "https://openlegislation.uk/eu-decision-2014-738/annex/division-3",
  "json_url": "https://openlegislation.uk/eu-decision-2014-738/annex/division-3.json",
  "legislation": "eudn/2014/738",
  "legislation_title": "Commission Implementing Decision of 9 October 2014 establishing best available techniques (BAT) conclusions, under Directive 2010/75/EU of the European Parliament and of the Council on industrial emissions, for the refining of mineral oil and gas (notified under document C(2014) 7155) (Text with EEA relevance) (2014/738/EU)",
  "legislation_url": "https://openlegislation.uk/eu-decision-2014-738",
  "path": "annex/division/3",
  "kind": "division",
  "number": null,
  "heading": "DEFINITIONS",
  "text": "For the purpose of these BAT conclusions, the following definitions apply:\nTerm used\nDefinition\nUnit\nA segment/subpart of the installation in which a specific processing operation is conducted\nNew unit\nA unit first permitted on the site of the installation following the publication of these BAT conclusions or a complete replacement of a unit on the existing foundations of the installation following the publication of these BAT conclusions\nExisting unit\nA unit which is not a new unit\nProcess off-gas\nThe collected gas generated by a process which must be treated e.g. in an acid gas removal unit and a sulphur recovery unit (SRU)\nFlue-gas\nThe exhaust gas exiting a unit after an oxidation step, generally combustion (e.g. regenerator, Claus unit)\nTail gas\nCommon name of the exhaust gas from an SRU (generally Claus process)\nVOC\nVolatile organic compounds as defined in Article 3(45) of Directive 2010/75/EU\nNMVOC\nVOC excluding methane\nDiffuse VOC emissions\nNon-channelled VOC emissions that are not released via specific emission points such as stacks. They can result from ‘area’ sources (e.g. tanks) or ‘point’ sources (e.g. pipe flanges)\nNOX expressed as NO2\nThe sum of nitrogen oxide (NO) and nitrogen dioxide (NO2) expressed as NO2\nSOX expressed as SO2\nThe sum of sulphur dioxide (SO2) and sulphur trioxide (SO3) expressed as SO2\nH2S\nHydrogen sulphide. Carbonyl sulphide and mercaptan are not included\nHydrogen chloride expressed as HCl\nAll gaseous chlorides expressed as HCl\nHydrogen fluoride expressed as HF\nAll gaseous fluorides expressed as HF\nFCC unit\nFluid catalytic cracking: a conversion process for upgrading heavy hydrocarbons, using heat and a catalyst to break larger hydrocarbon molecules into lighter molecules\nSRU\nSulphur recovery unit. See definition in Section 1.20.3\nRefinery fuel\nSolid, liquid or gaseous combustible material from the distillation and conversion steps of the refining of crude oil.\nExamples are refinery fuel gas (RFG), syngas and refinery oils, pet coke\nRFG\nRefinery fuel gas: off-gases from distillation or conversion units used as a fuel\nCombustion unit\nUnit burning refinery fuels alone or with other fuels for the production of energy at the refinery site, such as boilers (except CO boilers), furnaces, and gas turbines.\nContinuous measurement\nMeasurement using an ‘automated measuring system’ (AMS) or a ‘continuous emission monitoring system’ (CEMS) permanently installed on site\nPeriodic measurement\nDetermination of a measurand at specified time intervals using manual or automated reference methods\nIndirect monitoring of emissions to air\nEstimation of the emissions concentration in the flue-gas of a pollutant obtained through an appropriate combination of measurements of surrogate parameters (such as O2 content, sulphur or nitrogen content in the feed/fuel), calculations and periodic stack measurements. The use of emission ratios based on S content in the fuel is one example of indirect monitoring. Another example of indirect monitoring is the use of PEMS\nPredictive Emissions monitoring system (PEMS)\nSystem to determine the emissions concentration of a pollutant based on its relationship with a number of characteristic continuously monitored process parameters (e.g. fuel-gas consumption, air/fuel ratio) and fuel or feed quality data (e.g. the sulphur content) of an emission source\nVolatile liquid hydrocarbon compounds\nPetroleum derivatives with a Reid vapour pressure (RVP) of more than 4 kPa, such as naphtha and aromatics\nRecovery rate\nPercentage of NMVOC recovered from the streams conveyed into a vapour recovery unit (VRU)",
  "extent": "E+W+S+N.I.",
  "status": null,
  "version": "current",
  "annotations": [],
  "outstanding_effects": [],
  "provenance": {
    "source": "legislation.gov.uk",
    "source_url": "https://www.legislation.gov.uk/eudn/2014/738/annex/division/3",
    "retrieved_at": "2026-11-01T15:14:36.977162+00:00"
  },
  "licence": "Open Government Licence v3.0",
  "licence_url": "https://www.nationalarchives.gov.uk/doc/open-government-licence/version/3/",
  "attribution": "Contains public sector information licensed under the Open Government Licence v3.0. Source: legislation.gov.uk, The National Archives."
}