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The Environmental Authorisations (Scotland) Regulations 2018

Type Scottish-Statutory-Instrument

Publication 2018-06-28

Last updated 2025-11-01

State In force

Jurisdiction Scotland

Department King's Printer for Scotland

Source legislation.gov.uk

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unless SEPA determines that a different frequency of periodic monitoring is appropriate on the basis of a systematic appraisal of the risk of contamination of soil and groundwater,

(b) conditions to ensure appropriate monitoring and management of waste generated by the installation,

(c) conditions to ensure suitable emission monitoring requirements specifying measurement methodology, frequency and evaluation procedure,

(d) conditions relating to conditions other than normal operating conditions such as start-up and shut-down operations, leaks, malfunctions, momentary stoppages and definitive cessation of operations,

(e) conditions aimed at minimising long-distance or transboundary pollution,

(f) conditions for assessing compliance with the emission limit values or a reference to the applicable requirements specified elsewhere,

(g) conditions requiring the authorised person to supply SEPA regularly, and at least annually, with—

(i) the results of emission monitoring,

(ii) other necessary information,

(iii) where paragraph 11(6) of this schedule applies, a summary of the results of emission monitoring which allows a comparison with the emission levels associated with the best available techniques,

enabling SEPA to verify compliance with permit conditions,

(2) The requirements of this paragraph and paragraph 10 of this schedule apply to the activities listed in paragraph 46(10) without prejudice to animal welfare legislation.

Permits: emission limit values and environmental quality standards

10

(1) A permit for a schedule 20 emissions activity must, unless sub-paragraph (2) applies, include emission limit values for—

(a) polluting substances listed in paragraph 2,

(b) other polluting substances,

likely to be emitted in significant quantities from an installation, having regard to the nature of the pollutant, and the potential for emissions to transfer pollution from one environmental medium to another.

(2) SEPA may supplement or replace an emission limit value by an equivalent parameter or technical measure ensuring an equivalent level of protection for the environment.

(3) An emission limit value set pursuant to sub-paragraph (1) must apply at the point at which the emissions leave the installation with any dilution before that point being disregarded for the purpose of determining the emission limit value.

(4) Where relevant BAT conclusions contain an emission level associated with the best available techniques, an emission limit value must ensure that, under normal operating conditions, emissions do not exceed the emission levels associated with the best available techniques laid down in those BAT conclusions.

(5) In order to meet the requirements of sub-paragraph (4), emission limit values may—

(a) be set at emission levels that do not exceed the emission levels associated with the best available techniques and be expressed for the same or a shorter period of time, and under the same reference conditions, as for the emission levels associated with the best available techniques, or

(b) be set at different emission levels than those in sub-paragraph (a) in terms of values, periods of time or reference conditions.

(6) Where an emission limit value is set at a different emission level, in terms of values, periods of time, and reference conditions in accordance with sub-paragraph (5)(b), SEPA must—

(a) assess the results of emissions monitoring at least annually in order to ensure that emissions under normal operating conditions have not exceeded the emission levels associated with the best available techniques during that period, and

(b) ensure that the results of emissions monitoring are available for the same period of time and reference conditions as for the emission levels associated with the best available techniques.

(7) SEPA may grant a derogation to the emission limit values required by sub-paragraph (4) on application by the authorised person requesting a variation, where—

(a) an assessment shows that achievement of the emission levels associated with the best available techniques as described in any applicable BAT conclusions relevant to the activity as determined by SEPA, would lead to disproportionately higher costs compared to environmental benefits due to—

(i) the geographical location or local environmental conditions of the installation, or

(ii) the technical characteristics of the installation,

(b) the emission limit value set—

(i) does not exceed the emission limit values set out in schedules 21 to 24 for a particular industrial emissions activity,

(ii) ensures that no significant pollution is caused and that a high level of protection of the environment as a whole is achieved, and

(c) a schedule to the permit specifies the reasons for setting a less strict emission limit value, including the result of the assessment under head (a) and the justification for the conditions imposed.

(8) SEPA may take into account the effect of a wastewater treatment plant when determining the emission limit values applying in relation to indirect releases of polluting substances into water from an installation provided that—

(a) doing so does not lead to higher levels of pollution in the environment, and

(b) an equivalent level of protection of the environment as a whole is achieved.

(9) Where relevant BAT conclusions describe best available techniques, but do not contain an emission level associated with the techniques, an emission limit value must—

(a) be determined by giving special consideration to the principles specified in paragraph 4, and

(b) ensure a level of environmental protection equivalent to the techniques described in the BAT conclusions.

(10) Where permit conditions are based on best available techniques not described in any relevant BAT conclusions and which do not contain an emission level associated with those techniques, an emission limit value must—

(a) be determined by giving special consideration to the principles specified in paragraph 4 of this schedule,

(b) ensure a level of environmental protection equivalent to the best available techniques described in the BAT conclusions.

(11) In this paragraph—

“equivalent level of protection” means achieving the equivalent percent reduction in concentration of each relevant pollutant when using the downstream wastewater treatment plant, whilst ignoring any dilution from other wastewater streams, that would be achieved through applying the emission limits associated with best available techniques at the point of discharge from the installation,

“less strict emission limit value” means a value that is higher than the value that would otherwise be set if based on best available techniques.

Exception for the testing and use of emerging techniques

11

SEPA may, on determining an application for a variation by an authorised person, or as part of an application for a permit, set less strict conditions than those that would otherwise be required by paragraphs 4(e) and 10(4) of this schedule for the purpose of the testing and use of an emerging technique provided that—

(a) the less strict conditions apply for a period of time not to exceed 9 months, and

(b) after that period of time—

(i) use of the technique stops, or

(ii) the activity achieves at least the emission levels associated with the best available techniques.

Permits: surrender applications

12

(1) In considering the impact on the environment resulting from the carrying on, and cessation of a schedule 20 emissions activity in accordance with paragraph 14(1) of schedule 1, SEPA must consider—

(a) the condition of the soil and groundwater affected by the activity, including at the site of the installation, and

(b) any changes from the condition of the site as described in the site report, and where applicable, the baseline report.

(2) SEPA must not grant an application for surrender for a schedule 20 emissions activity unless—

(a) the authorised person has taken the necessary measures to address any significant pollution of soil or groundwater by relevant hazardous substances compared to the state established in the baseline report, taking account of the technical feasibility of such measures, and

(b) where the contamination of soil and groundwater at the site poses a significant risk to human health or the environment as a result of the regulated activity, the authorised person has taken the necessary actions to remove, control, contain or reduce any hazardous substances so that the site ceases to pose such a risk, taking account of its current or approved future use.

Permits: reviews

13

(1) SEPA must periodically review the conditions of permits for schedule 20 emissions activities, and where necessary, update permit conditions to ensure compliance with this schedule.

(2) SEPA must, in reviewing permit conditions—

(a) consider any information resulting from monitoring or inspections,

(b) where that review takes place by virtue of sub-paragraph (4)(a)—

(i) take into account the BAT conclusions prompting the review,

(ii) take into account any BAT conclusions for other activities within the installation published since the permit was granted or last reviewed,

(iii) reconsider any derogations to emission limit values associated with BAT conclusions.

(3) Where a review takes place by virtue of any of sub-paragraph (4)(b) to (f), SEPA may take into account any relevant BAT conclusions and reconsider any derogations to emission limit values associated with those BAT conclusions.

(4) In this paragraph, “periodically” means—

(a) within 4 years of the publication of decision on BAT conclusions relating to the main activity of the installation,

(b) when necessary to comply with a new or revised environmental quality standard,

(c) when pollution caused by an installation is of such significance that the emission limit values in the permit need to be reviewed or new emission limit values need to be included,

(d) when the operational safety of the activities carried out in the installation requires that other techniques be used,

(e) when there are developments in the best available techniques that allow for significant reduction of emissions in a case where the regulated activities are not covered by any of the BAT conclusions, or

(f) when considered appropriate by SEPA.

Environmental inspection plans

14

(1) SEPA must maintain an environmental inspection plan in respect of schedule 20 emissions activities.

(2) An environmental inspection plan must—

(a) include a general assessment of relevant significant environmental issues,

(b) include a list of the installations covered by the plan,

(c) provide for a procedure for drawing up programmes for routine environmental inspections under paragraph 15(1)(b) of this schedule,

(d) provide a procedure for non-routine environmental inspections under paragraph 15(3) and (5) of this schedule,

(3) An environmental inspection plan may be comprised of one or more plans, documents or strategies, and may be prepared at a national, regional or local level.

(4) SEPA must regularly review, and where appropriate update or replace, an environmental inspection plan.

Environmental inspections

15

(1) SEPA must—

(a) conduct environmental inspections of schedule 20 emissions activities,

(b) regularly draw up programmes for environmental inspections based on the environmental inspection plan, including the frequency of site visits for different types of installations.

(2) The period between site visits for the purpose of an environmental inspection carried out under the environmental inspection plan, and not falling under sub-paragraphs (3) or (5) must be based on a systematic appraisal of risk and must not exceed—

(a) one year for installations posing the highest risk,

(b) three years for installations posing the lowest risk.

(3) SEPA must conduct an environmental inspection to investigate as soon as possible—

(a) serious environmental complaints,

(b) serious environmental accidents,

(4) SEPA may conduct an environmental inspection—

(a) before granting a permit,

(b) upon the review or variation of a permit.

(5) An additional site visit must take place within 6 months of any environmental inspection which identifies an important case of non-compliance with permit conditions.

(6) SEPA must prepare a report on each site visit describing—

(a) findings regarding compliance with the permit,

(b) conclusions on whether any further action is needed.

(7) SEPA must provide a copy of a site visit report prepared in accordance with sub-paragraph (6) to the authorised person within 2 months of the site visit taking place.

(8) SEPA must include the particulars of a site visit report in the register within 4 months of the site visit taking place.

(9) SEPA must ensure that the authorised person takes all necessary actions identified in a site visit report within a reasonable period of time as assessed by SEPA.

(10) In this paragraph—

“site visit” includes any measures undertaken to check compliance at a site,

“systematic appraisal of risk” means an appraisal by SEPA of the environmental risks of an installation based on—the potential and actual impacts on human health and the environment taking into account the levels and types of emissions, the sensitivity of the local environment and the risk of accidents,the record of compliance with permit conditions,participation by the authorised person in an environmental management and audit scheme.

Proposed change in operation

16

(1) SEPA must ensure that a permit for a schedule 20 emissions activity includes such conditions as it considers appropriate to ensure that the authorised person informs SEPA of a proposed change in operation which may have consequences for the environment in advance of making any such change unless sub-paragraph (2) applies.

(2) This sub-paragraph applies where—

(a) the authorised person applies for a variation of the permit before a change in operation is made, and

(b) the proposed change is addressed in the application.

Public consultation

17

(1) Public consultation in accordance with paragraph 8 of schedule 1 is required in relation to the following—

(a) an application for a permit for a schedule 20 emissions activity,

(b) an application to vary a permit for a schedule 20 emissions activity where the application is as a result of a substantial change,

(c) an application to vary a permit for a schedule 20 emissions activity where the grant of the application would set less strict emission level values under paragraph 10(6) of this schedule,

(d) a SEPA-initiated variation to a permit for a schedule 20 emissions activity where—

(i) the variation would set less strict emission level values under paragraph 10(6) of this schedule, or

(ii) the proposed variation is as a result of a review of permit conditions required by paragraph 13(4)(c) of this schedule.

(2) Where public consultation is required under sub-paragraph (1), in addition to the requirements in paragraph 8 of schedule 1, SEPA must—

(a) ensure that the following additional information is publicised in such manner as SEPA thinks fit—

(i) where not otherwise included in the application itself, a description of the matters included in paragraph 8(1) of schedule 1,

(ii) where applicable, the fact that a decision by SEPA is subject to an environmental impact assessment,

(iii) where applicable, the fact that a decision by SEPA is subject to consultations with neighbouring states as a result of paragraph 19 of this schedule,

(iv) where applicable, the details of the proposal for a SEPA-initiated variation under paragraph 8(1)(d) of schedule 1,

(v) the nature of possible decisions, or where one exists, the draft decision,

(b) provide copies of the following—

(i) the main reports and advice issued to SEPA or, where applicable, issued to the Scottish Ministers and provided to SEPA, at the time when the public concerned were informed about the relevant application or SEPA initiated variation,

(ii) any relevant information obtained, or conclusion arrived at in relation to an environmental impact assessment relevant to the determination of the application or SEPA initiated variation by virtue of paragraph 12 of schedule 19, which became available to the applicant or, in the case of a SEPA-initiated variation, to the authorised person, subsequent to the publication of the information in sub-paragraph (2)(a).

(3) Paragraph 8(2), (3), (4), and (5) of schedule 1 apply to the duties in sub-paragraph (2) as if the reference to sub-paragraph (1)(a) or (b) in sub-paragraph 8(2) of schedule 1 were a reference to sub-paragraph (2).

PART3 — SEPA and Scottish Ministers’ duties

SEPA: trans-boundary effects

18

(1) SEPA must notify the Scottish Ministers of any application or a proposal for a SEPA-initiated variation of a permit for a schedule 20 emissions activity which if granted or put into effect is likely to have significant negative effects on the environment of a neighbouring state.

(2) For the purposes of this paragraph and paragraph 19 of this schedule, a “neighbouring state” includes—

(a) a member state of the European Union,

(b) Iceland, Liechtenstein and Norway.

Scottish Ministers’ duties: trans-boundary effects

19

(1) This paragraph applies where—

(a) the Scottish Ministers are aware that the grant of an application or a proposal for a SEPA initiated variation of a permit for a schedule 20 emissions activity is likely to have significant negative effects on the environment of a neighbouring state, or

(b) a neighbouring state requests information about an application or a proposal for a SEPA-initiated variation in relation to a schedule 20 emissions activity.

(2) The Scottish Ministers must, as soon as reasonably practicable—

(a) send the particulars of the application or SEPA initiated variation to that neighbouring state,

(b) inform that neighbouring state of the relevant information,

(d) allow such reasonable period as may have been agreed with the neighbouring state to ensure that the state and the public concerned are given an opportunity to forward their representations on the information supplied in accordance with heads (a) and (b),

(e) notify SEPA and the authorised person that they have complied with the obligations in this sub-paragraph.

(3) Where SEPA receives a notice under sub-paragraph (2)(e), it must not determine the application or make the SEPA-initiated variation until the Scottish Ministers have—

(a) notified SEPA that the consultation described in sub-paragraph (2)(c) has been completed,

(d) sent SEPA any representations made by the neighbouring state.

(4) In this paragraph “relevant information” includes the information made available to the public in accordance with paragraph 16 of this schedule and paragraph 8 of schedule 1.

Scottish Ministers’ duties: access to justice

20

(1) Any non-governmental organisation promoting environmental protection and meeting any necessary requirements under the law is, in relation to any decision subject to public consultation under paragraph 8 of schedule 1 as a result of the application of paragraph 16 of this schedule, for the purposes of seeking review of that decision deemed to have sufficient interest in the subject matter of a petition for judicial review as required by section 27B(2)(a) of the Court of Session Act 1988.

(2) The Scottish Ministers must ensure that information is made available to the public in relation to appeals to the Scottish Ministers under regulation 55 and judicial review proceedings in the Court of Session.

PART 4 — Activities

CHAPTER 1 — Energy industries

1

Combustion of fuels in installations with a total rated thermal input of 50 MW or more.

2

Refining of mineral oil and gas.

3

Production of coke.

4

Gasification or liquefaction of—

(a) coal,

(b) other fuels in installations with a total rated thermal input of 20 MW or more.

CHAPTER 2 — Production and processing of metals

5

Metal ore (including sulphide ore) roasting or sintering.

6

Production of pig iron or steel (primary or secondary fusion) including continuous casting, with a capacity exceeding 2.5 tonnes per hour.

7

Processing of ferrous metals—

(a) operation of hot-rolling mills with a capacity exceeding 20 tonnes of crude steel per hour,

(b) operation of smitheries with hammers the energy of which exceeds 50 kilojoule per hammer, where the calorific power used exceeds 20 MW,

8

Operation of ferrous metal foundries with a production capacity exceeding 20 tonnes per day.

9

Processing of non-ferrous metals—

(a) production of non-ferrous crude metals from ore, concentrates or secondary raw materials by metallurgical, chemical or electrolytic processes,

(b) melting, including the alloyage, of non-ferrous metals, including recovered products and operation of non-ferrous metal foundries, with a melting capacity exceeding 4 tonnes per day for lead and cadmium or 20 tonnes per day for all other metals.

10

Surface treatment of metals or plastic materials using an electrolytic or chemical process where the aggregated volume of the treatment vats exceeds 30 m³.

CHAPTER 3 — Mineral industry

11

Production of cement, lime and magnesium oxide—

(a) production of cement clinker in rotary kilns with a production capacity exceeding 500 tonnes per day or in other kilns with a production capacity exceeding 50 tonnes per day,

(b) production of lime in kilns with a production capacity exceeding 50 tonnes per day,

12

Production of asbestos or the manufacture of asbestos-based products.

13

Manufacture of glass including glass fibre with a melting capacity exceeding 20 tonnes per day.

14

Melting mineral substances including the production of mineral fibres with a melting capacity exceeding 20 tonnes per day.

15

Manufacture of ceramic products by firing, in particular roofing tiles, bricks, refractory bricks, tiles, stoneware or porcelain with a production capacity exceeding 75 tonnes per day and/or with a kiln capacity exceeding 4 m³ and with a setting density per kiln exceeding 300 kg/m³.

CHAPTER 4 — Chemical industry

16

Production of organic chemicals—

(a) simple hydrocarbons (linear or cyclic, saturated or unsaturated, aliphatic or aromatic),

(b) oxygen-containing hydrocarbons such as alcohols, aldehydes, ketones, carboxylic acids, esters and mixtures of esters, acetates, ethers, peroxides and epoxy resins,

(d) nitrogenous hydrocarbons such as amines, amides, nitrous compounds, nitro compounds or nitrate compounds, nitriles, cyanates, isocyanates,

(e) phosphorus-containing hydrocarbons,

(f) halogenic hydrocarbons,

(g) organometallic compounds,

(h) plastic materials (polymers, synthetic fibres and cellulose-based fibres),

(i) synthetic rubbers,

(j) dyes and pigments,

(k) surface-active agents and surfactants.

17

Production of inorganic chemicals—

(a) gases, such as ammonia, chlorine or hydrogen chloride, fluorine or hydrogen fluoride, carbon oxides, sulphur compounds, nitrogen oxides, hydrogen, sulphur dioxide, carbonyl chloride,

(b) acids, such as chromic acid, hydrofluoric acid, phosphoric acid, nitric acid, hydrochloric acid, sulphuric acid, oleum, sulphurous acids,

(d) salts, such as ammonium chloride, potassium chlorate, potassium carbonate, sodium carbonate, perborate, silver nitrate,

(e) non-metals, metal oxides or other inorganic compounds such as calcium carbide, silicon, silicon carbide.

18

Production of phosphorous-, nitrogen- or potassium-based fertilisers (simple or compound fertilisers).

19

Production of plant protection products or of biocides.

20

Production of pharmaceutical products including intermediates.

21

Production of explosives.

22

In this Chapter, “production” means the production on an industrial scale by chemical or biological processing of substances or groups of substances listed in paragraphs 16 to 21.

CHAPTER 5 — Waste management

23

Disposal or recovery of hazardous waste with a capacity exceeding 10 tonnes per day involving one or more of the following activities—

(a) biological treatment,

(b) physico-chemical treatment,

(d) repackaging prior to submission to any of the other activities listed in this paragraph and paragraph 24,

(e) solvent reclamation/regeneration,

(f) recycling or reclamation of inorganic materials other than metals or metal compounds,

(g) regeneration of acids or bases,

(h) recovery of components used for pollution abatement,

(i) recovery of components from catalysts,

(j) oil re-refining or other reuses of oil,

(k) surface impoundment.

24

Disposal or recovery of waste in waste incineration plants or in waste co-incineration plants—

(a) for non-hazardous waste with a capacity exceeding 3 tonnes per hour,

(b) for hazardous waste with a capacity exceeding 10 tonnes per day.

25

(1) Disposal of non-hazardous waste with a capacity exceeding 50 tonnes per day involving one or more of the following activities, and excluding activities covered by the Urban Waste-water Treatment Directive—

(a) biological treatment,

(b) physico-chemical treatment,

(d) treatment of slags and ashes,

(e) treatment in shredders of metal waste, including waste electrical and electronic equipment and end-of-life vehicles and their components.

(2) Recovery, or a mix of recovery and disposal, of non-hazardous waste with a capacity exceeding 75 tonnes per day involving one or more of the following activities, and excluding activities covered by the Urban Waste-water Treatment Directive—

(a) biological treatment,

(b) pre-treatment of waste for incineration or co-incineration,

(d) treatment in shredders of metal waste, including waste electrical and electronic equipment and end-of-life vehicles and their components.

(3) When the only waste treatment activity carried out under sub-paragraph (2) is anaerobic digestion, the capacity threshold for this activity must be 100 tonnes per day.

26

Landfills receiving more than 10 tonnes of waste per day or with a total capacity exceeding 25,000 tonnes, excluding landfills of inert waste.

27

Temporary storage of hazardous waste not covered under paragraph 26, pending any of the activities in paragraphs 23, 24, 26 or 28 with a total capacity exceeding 50 tonnes, excluding temporary storage, pending collection, on the site where the waste is generated.

28

Underground storage of hazardous waste with a total capacity exceeding 50 tonnes.

29

In this chapter, “inert waste” has the meaning given in paragraph 4 of schedule 13.

CHAPTER 6 — Other activities

30

Pre-treatment (operations such as washing, bleaching, mercerisation) or dyeing of textile fibres or textiles where the treatment capacity exceeds 10 tonnes per day.

31

Tanning of hides and skins where the treatment capacity exceeds 12 tonnes of finished products per day.

32

(1) Operating slaughterhouses with a carcass production capacity greater than 50 tonnes per day.

(2) Treatment and processing, other than exclusively packaging, of the following raw materials, whether previously processed or unprocessed, intended for the production of food or feed from—

(a) only animal raw materials (other than exclusively milk) with a finished product production capacity greater than 75 tonnes per day,

(b) only vegetable raw materials with a finished product production capacity greater than 300 tonnes per day or 600 tonnes per day where the installation operates for a period of no more than 90 consecutive days in any year,

(c) as shown in Graph 1, animal and vegetable raw materials, both in combined and separate products (except where the raw material is exclusively milk), with a finished product production capacity in tonnes per day greater than—

(i) 75 if A is equal to 10 or more,

(ii) 300- (22.5 × A) in any other case,

where ‘A’ is the portion of animal material (in percent of weight) of the finished product production capacity and in the above calculations, packaging is not to be included in the final weight of the product,

(d) treatment and processing of milk only, the quantity of milk received being greater than 200 tonnes per day (average value on an annual basis).

33

Disposal or recycling of animal carcases or animal waste with a treatment capacity exceeding 10 tonnes per day.

34

Intensive rearing of poultry or pigs—

(a) with more than 40,000 places for poultry,

(b) with more than 2,000 places for production pigs (over 30 kg),

35

Surface treatment of substances, objects or products using organic solvents, in particular for dressing, printing, coating, degreasing, waterproofing, sizing, painting, cleaning or impregnating, with an organic solvent consumption capacity of more than 150 kg per hour or more than 200 tonnes per year.

36

Production of carbon (hard-burnt coal) or electrographite by means of incineration or graphitisation.

37

Capture of CO₂ streams from industrial emissions activities for the purposes of geological storage pursuant to Directive 2009/31/EC of the European Parliament and of the Council of 23 April 2009 on geological storage of carbon dioxide and amending Council Directive 85/337/EEC, European Parliament and Council Directives 2000/60/EC, 2001/80/EC, 2004/35/EC, 2006/12/EC, 2008/1/EC and Regulation (EC) No 1013/2006.

38

Preservation of wood and wood products with chemicals with a production capacity exceeding 75 m³ per day other than exclusively treating against sapstain,

39

Independently operated treatment of wastewater not covered by Directive 91/271/EEC and discharged by an installation covered by this schedule,

40

In this Chapter—

“animal” includes a bird or a fish,

“food” includes drink, articles and substances of no nutritional value which are used for human consumption, and articles and substances used as ingredients in the preparation of food,

“wood” includes any product consisting wholly or mainly of wood.

SCHEDULE21 — OPERATING A LARGE COMBUSTION PLANT

PART1 — Scope and interpretation

Scope and interpretation: operating a large combustion plant

1

(1) This schedule applies to operating a large combustion plant.

(2) “Large combustion plant” means a combustion plant where the total rated thermal input of which is equal to or greater than 50 MW, irrespective of the type of fuel used, but does not include—

(a) plants in which the products of combustion are used for the direct heating, drying, or any other treatment of objects or materials,

(b) post-combustion plants designed to purify the waste gases by combustion which are not operated as independent combustion plants,

(d) facilities for the conversion of hydrogen sulphide into sulphur,

(e) reactors used in the chemical industry,

(f) coke battery furnaces,

(g) cowpers,

(h) any technical apparatus used in the propulsion of a vehicle, ship or aircraft,

(i) gas turbines and gas engines used on offshore platforms,

(j) plants which use any solid or liquid waste as a fuel other than waste that is biomass.

Interpretation: general

2

In this schedule—

“CCGT” means combined cycle gas turbines,

“determinative fuel” means the fuel which, amongst all fuels used in a multi-fuel firing combustion plant using the distillation and conversion residues from the refining of crude oil for own consumption alone or with other fuels, has the highest emission limit value as set out in Part 3 of this schedule, or, in the case of several fuels having the same emission limit value, the fuel having the highest thermal input amongst those fuels,

“diesel engine” means an internal combustion engine which operates according to the diesel cycle and uses compression ignition to burn fuel,

“gas engine” means an internal combustion engine which operates according to the Otto cycle and uses spark ignition or, in the case of dual fuel engines, compression ignition to burn fuel,

“gas turbine” means any rotating machine which converts thermal energy into mechanical work, consisting mainly of a compressor, a thermal device in which fuel is oxidised in order to heat the working fluid, and a turbine,

“indigenous solid fuel” means a naturally occurring solid fuel fired in a combustion plant specifically designed for that fuel and extracted locally,

“multi-fuel firing combustion plant” means any combustion plant which may be fired simultaneously or alternately by two or more types of fuel,

“operating hours” means the time, expressed in hours, during which a combustion plant, in whole or in part, is operating and discharging emissions into the air, excluding start-up and shut-down periods,

“rate of desulphurisation” means the ratio over a given period of time of the quantity of sulphur which is not emitted into air by a combustion plant to the quantity of sulphur contained in the solid fuel which is introduced into the combustion plant facilities and which is used in the plant over the same period of time,

“stack” means a structure containing one or more flues providing a passage for waste gases in order to discharge them into the air.

Aggregation rules

3

(1) Where the waste gases of two or more separate combustion plants are discharged through a common stack—

(a) the combination formed by such plants is to be considered a single combustion plant, and

(b) their capacities added together for the purpose of calculating the total rated thermal input.

(2) Where two or more separate combustion plants—

(a) have been granted a permit for the first time on or after 1 July 1987 or in relation to which a complete application for a permit has been submitted on or after that date, and

(b) are installed in such a way that taking technical and economic factors into account, their waste gases could, in the judgement of SEPA, be discharged through a common stack—

(i) the combination formed by such plants is to be considered as a single combustion plant, and

(ii) their capacities added for the purpose of calculating the total rated thermal input.

(3) For the purpose of calculating the total rated thermal input of a combination of combustion plants referred to in sub-paragraphs (1) and (2), individual combustion plants with a rated thermal input below 15 MW are not to be considered.

PART2 — Amendments to common framework provisions

Authorisations: permits

4

(1) Operating a large combustion plant may only be authorised by permit.

(2) A permit for operating a large combustion plant must not be granted unless the permit gives effect to the requirements of this schedule.

Permits: discharge of waste gases

5

(1) Waste gases from large combustion plants must be discharged in a controlled way by means of a stack, containing one or more flues.

(2) The height of the stack must be calculated in such a way as to safeguard human health and the environment.

Permits: emission limit values

6

(1) All permits for operating a large combustion plant which have been granted before 7 January 2013, or for which a complete application was submitted before that date, provided that such plants were in operation not later than 7 January 2014 must include conditions ensuring that emissions into the air from these plants do not exceed the emission limit values set out in Chapter 1 of Part 3 of this schedule.

(2) All permits for operating a large combustion plant other than those described in sub-paragraph (1) must include conditions ensuring that emissions into the air from these plants do not exceed the emission limit values set out in Chapter 2 of Part 3 of this schedule.

(3) Emission limit values and minimum rates of desulphurisation apply to the emissions of each common stack in relation to the total rated thermal input of the entire large combustion plant.

(4) Where Part 3 of this schedule provides that emission limit values may be applied for a part of a large combustion plant with a limited number of operating hours, those limit values apply to the emissions of that part of the plant, but must be set in relation to the total rated thermal input of the entire combustion plant.

(5) Where a large combustion plant is extended, the emission limit values set out in Chapter 2 of Part 3 of this schedule—

(a) apply to the extended part of the plant affected by the change,

(b) must be set in relation to the total rated thermal input of the entire combustion plant.

(6) Sub-paragraph (7) applies where there is an extension to a large combustion plant that—

(a) may have consequences for the environment, and

(b) affects a part of the plant with a rated thermal input of 50 MW or more.

(7) Where this sub-paragraph applies, the emission limit values as set out in Chapter 2 of Part 3 of this schedule apply to the part of the plant referred to in sub-paragraph (5) which has changed in relation to the total rated thermal input of the entire combustion plant.

Emission limit value exemptions: general

7

The emission limit values set out in Chapters 1 and 2 of Part 3 of this schedule do not apply to the following large combustion plants—

(a) diesel engines,

(b) recovery boilers within installations for the production of pulp.

Emission limit value exemptions: fuel shortages and interruptions

8

(1) SEPA may, on application by the authorised person, grant an exemption for a maximum of 6 months from the obligation to comply with the emission limit value for sulphur dioxide set out in Chapters 1 and 2 of Part 3 of this schedule where—

(a) a large combustion plant normally uses low-sulphur fuel, and

(b) the authorised person is unable to comply with those limit values because of an interruption in the supply of low-sulphur fuel resulting from a serious shortage.

(2) SEPA may, on application by the authorised person, grant an exemption for a maximum of 10 days, unless there is an overriding need to maintain energy supplies, from the obligation to comply with emission limit values set out in Chapters 1 and 2 of Part 3 of this schedule where—

(a) a large combustion plant normally uses only gaseous fuel,

(b) the authorised person has to resort exceptionally to the use of other fuels because of a sudden interruption in the supply of gas, and

(3) An application for an exemption—

(a) under sub-paragraph (1), must be made to SEPA in writing,

(b) under sub-paragraph (2)—

(i) must be made immediately and in advance of the need to use other fuels,

(ii) may be made in writing, or by other means,

(d) will be determined by SEPA within the period as considered appropriate by SEPA in the circumstances.

(4) SEPA must notify the authorised person in writing of an exemption granted under sub-paragraph (3) where practicable to do so.

(5) SEPA must immediately inform the Scottish Ministers of any exemption granted under sub-paragraph (1) or (2).

Emission limit value exemptions: desulphurisation for combustion plants firing indigenous solid fuel

9

(1) SEPA may apply the minimum rates of desulphurisation set out in Chapter 5 of Part 3 of this schedule where the circumstances in sub-paragraph (2) or (3) apply.

(2) This sub-paragraph applies to a large combustion plant that fires indigenous solid fuel, where—

(a) due to the characteristics of that fuel, the plant cannot comply with the emission limit value for sulphur dioxide required by paragraphs 6(1) and (2) of this schedule,

(b) the authorised person has submitted a technical report to SEPA,

(d) the minimum rates of desulphurisation are applied as a monthly average limit value.

(3) This sub-paragraph applies to a large combustion plant that fires indigenous solid fuel which co-incinerates waste, where—

(a) due to the characteristics of that fuel, the plant cannot comply with the Cproc values for sulphur dioxide set out in paragraphs 21(4) and (5) of schedule 22, and

(b) the minimum rates of desulphurisation are applied as a monthly average limit value.

(4) Where the minimum rate of desulphurisation is applied in the circumstances described in sub-paragraph (2), Cwaste as referred to in paragraph 19 of schedule 22 is equal to 0 mg/Nm³.

Carbon capture and storage

10

(1) SEPA must assess whether the following conditions are met for all large combustion plants with a rated electrical output of 300 megawatts or more, for which the first permit was granted after 25 June 2009—

(a) suitable storage sites are available,

(b) transport facilities are technically and economically feasible, and

(2) In assessing whether the conditions in sub-paragraph (1) are met, SEPA must also take into account other information, and in particular information concerning the protection of the environment and human health.

(3) Where the conditions in sub-paragraph (1) are met, SEPA must include such conditions as it considers appropriate to ensure that suitable space on the authorised place is set aside for the equipment necessary to capture and compress carbon dioxide.

(4) In this paragraph, “first permit” means a permit under either the Pollution Prevention and Control (Scotland) Regulations 2012 or the Pollution Prevention and Control (Scotland) Regulations 2000.

Abatement equipment malfunction or breakdown

11

(1) SEPA must ensure permits for operating a large combustion plant include such conditions as it considers appropriate to give effect to sub-paragraphs (a) to (c)—

(a) in the event that normal operation is not restored within 24 hours of a break-down, the authorised person must—

(i) reduce or stop operations, or

(ii) operate the plant using low polluting fuels,

(b) the authorised person must notify SEPA within 48 hours of the malfunction or breakdown of abatement equipment,

(2) SEPA may, on application by the authorised person, provide for an exemption to the time periods in sub-paragraph (1)(a) and (1)(c) where—

(a) there is an overriding need to maintain energy supplies, or

(b) the combustion plant with the breakdown would be replaced for a limited period by another plant which would cause an overall increase in emissions.

(3) An application for an exemption—

(a) under sub-paragraph (2)(a)—

(i) must be made immediately and in advance of the need to use other fuels,

(ii) may be made in writing, or by other means,

(b) under sub-paragraph (2)(b), must be made to SEPA in writing,

(d) will be determined by SEPA within the period as considered appropriate by SEPA in the circumstances.

(4) SEPA will notify the authorised person in writing of an exemption granted under sub-paragraph (2) where practicable to do so.

Emissions monitoring and compliance

12

(1) SEPA must ensure that a permit for operating a large combustion plant includes such conditions as it considers appropriate to ensure—

(a) monitoring of air polluting substances is carried out in accordance with Chapter 3 of Part 3 of this schedule,

(b) installation and functioning of the automated monitoring equipment is subject to control and annual surveillance tests as set out in Chapter 3 of Part 3 of this schedule,

(c) that the location of the sampling or measurement points to be used for emissions monitoring is as designated by SEPA,

(d) the recording and reporting of monitoring results to SEPA,

(e) where any of paragraphs 20(2), 21(4), 28(2), 29(3) of this schedule applies, the recording of the used operating hours,

(f) where more than 10 days over a year are invalidated as result of paragraph 37(2) of this schedule, adequate measures are taken to improve the reliability of the automated measuring system,

(g) where paragraph 33 of this schedule applies, that SEPA is informed of significant changes in the type of fuel used.

(2) In assessing compliance with emission limit valuesSEPA must have regard to the conditions set out in Chapter 4 of Part 3 of this schedule.

Multi-fuel firing combustion plants

13

(1) SEPA must, except where sub-paragraph (2) applies, set the emissions limit value for a multi-fuel large combustion plant involving the simultaneous use of two or more fuels by—

(a) taking the emission limit value for each individual fuel and pollutant corresponding to the total rated thermal input of the entire combustion plant as set out in Chapters 1 and 2 of Part 3 of this schedule,

(b) determining fuel-weighted emission limit values, by multiplying the individual emission limit value in head (a) by the thermal input delivered by each fuel, and dividing the total by the total thermal inputs delivered by all fuels,

(2) This sub-paragraph applies to a multi-fuel large combustion plant covered by paragraph 6(1) of this schedule, which uses the distillation and conversion residues from the refining of crude oil for own consumption, alone or with other fuels.

(3) Where sub-paragraph (2) applies, the following emission limit values may be set rather than the values set according to sub-paragraph (1)—

(a) where, during the operation of the combustion plant, the proportion contributed by the determinative fuel to the sum of the thermal inputs delivered by all fuels is 50% or more, the emission limit value set in Chapter 1 of Part 3 of this schedule for the determinative fuel,

(b) where the proportion contributed by the determinative fuel to the sum of the thermal inputs delivered by all fuels is less than 50%, the emission limit value is determined by—

(i) taking the emission limit values set out in Chapter 1 of Part 3 of this schedule for each of the fuels used, corresponding to the total rated thermal input of the combustion plant,

(ii) calculating the emission limit value of the determinative fuel by multiplying the emission limit value, determined for that fuel according to sub-head (i), by a factor of two, and subtracting from this product the emission limit value of the fuel used with the lowest emission limit value as set out in Chapter 1 of Part 3 of this schedule, corresponding to the total rated thermal input of the combustion plant,

(iii) determining the fuel-weighted emission limit value for each fuel used by multiplying the emission limit value determined under sub-heads (i) and (ii) by the thermal input of the fuel concerned and by dividing the total by the total thermal inputs delivered by all fuels,

(iv) aggregating the fuel-weighted emission limit values.

(4) Where a multi-fuel firing large combustion plant to which paragraph 6(1) of this schedule applies uses the distillation and conversion residues from the refining of crude-oil for its own consumption, alone or with other fuels, the average emission limit values for sulphur dioxide set out in Chapter 6 of Part 3 of this schedule may be applied instead of the emission limit values set according to sub-paragraphs (1) or (3) of this paragraph.

Monitoring and reporting

14

SEPA must ensure that a permit for operating a large combustion plant includes such conditions as it considers appropriate to ensure that the following information is reported to SEPA—

(a) the total rated thermal input (MW) of the combustion plant,

(b) the type of combustion plant—

(i) boiler,

(ii) gas turbine,

(iii) gas engine,

(iv) diesel engine,

(v) other, with specification of the type,

(d) the total annual emissions (tonnes per year) of sulphur dioxide, nitrogen oxides and dust (as total suspended particles),

(e) the number of operating hours of the combustion plant,

(f) the total annual amount of energy input, related to the net calorific value (TJ per year), broken down in terms of the following categories of fuel—

(i) coal,

(ii) lignite,

(iii) biomass,

(iv) peat,

(v) other solid fuels, with specification of type,

(vi) liquid fuels,

(vii) natural gas,

(viii) other gases, with specification of type.

Start-up and shut-down periods

15

The determination of start-up and shut-down periods for large combustion plants is to be in accordance with Commission Implementing Decision of 7 May 2012 concerning the determination of start-up and shut-down periods for the purposes of the Industrial Emissions Directive.

PART3 — Technical provisions relating to combustion plants

CHAPTER1 — Emission limit values for combustion plants referred to in paragraph 6(1)

Calculation of emission limit values

16

All emission limit values are to be calculated—

(a) at a temperature of 273.15K,

(b) a pressure of 101.3kPa,

(d) at a standardised O₂ content of—

(i) 6% for solid fuels,

(ii) 3% for combustion plants, other than gas turbines and gas engines using liquid and gaseous fuels,

(iii) 15% for gas turbines and gas engines.

Emission limit values for SO2 for combustion plants using solid or liquid fuels (with the exception of gas turbines and gas engines)

17

(1) Emission limit values (mg/Nm³) for SO₂ for combustion plants using solid or liquid fuels with the exception of gas turbines and gas engines where the circumstances in sub-paragraphs (2) to (4) do not apply are as stated in Table 1—

Total rated thermal input (MW)	Coal and lignite and other solid fuels	Biomass	Peat	Liquid Fuels
50-100	400	200	300	350

100-300	250	200	300	250

>300	200	200	200	200

(2) Combustion plants, using solid fuels which were granted a permit before 27 November 2002 or where a complete application for a permit was submitted before that date, provided that the plant was put into operation no later than 27 November 2003, and which do not operate more than 1,500 operating hours per year as a rolling average over a period of 5 years, are subject to an emission limit value for SO₂ of 800 mg/Nm³.

(3) Combustion plants using liquid fuels, which were granted a permit before 27 November 2002 or where a complete application for a permit was submitted before that date, provided that the plant was put into operation no later than 27 November 2003, and which do not operate more than 1,500 operating hours per year as a rolling average over a period of 5 years, are subject to an emission limit value for SO₂ of 850 mg/Nm³ in case of plants with a total rated thermal input not exceeding 300 MW and of 400 mg/Nm³ in case of plants with a total rated thermal input greater than 300 MW.

(4) A part of a combustion plant discharging its waste gases through one or more separate flues within a common stack, and which does not operate more than 1,500 operating hours per year as a rolling average over a period of 5 years, may be subject to the emission limit values set out in sub-paragraphs (2) and (3) in relation to the total rated thermal input of the entire combustion plant.

(5) Where sub-paragraph (4) applies, the emissions through each of those flues must be monitored separately.

Emission limit values for SO2 combustion plants using gaseous fuels (with the exception of gas turbines and gas engines)

18

(1) Emission limit values (mg/Nm³) for SO₂ for combustion plants using gaseous fuels with the exception of gas turbines and gas engines are, unless the circumstances in sub-paragraph (2) apply, as stated in Table 2—

In general	35
Liquefied gas	5
Low calorific gases from coke oven	400
Low calorific gases from blast furnace	200

(2) Combustion plants, firing low calorific gases from gasification of refinery residues, which were granted a permit before 27 November 2002 or where a complete application for a permit was submitted before that date, provided that the plant was put into operation no later than 27 November 2003, are subject to an emission limit value for SO₂ of 800 mg/Nm³.

Emission limit values for NOx for combustion plants using solid or liquid fuels (with the exception of gas turbines and gas engines)

19

(1) Emission limit values (mg/Nm³) for NOx for combustion plants using solid or liquid fuels with the exception of gas turbines and gas engines are, unless the circumstances in sub-paragraphs (2) to (6) are as stated in Table 3—

Total rated thermal input (MW)	Coal and lignite and other solid fuels	Biomass and Peat	Liquid fuels
(1)The emission limit value is 450 mg/Nm³ for the firing of distillation and conversion residues from the refining of crude-oil for own consumption in combustion plants with a total rated thermal input not exceeding 500 MW which were granted a permit before 27 November 2002 or where a complete application for a permit was submitted before that date, provided that the plant was put into operation no later than 27 November 2003.	(1)The emission limit value is 450 mg/Nm³ for the firing of distillation and conversion residues from the refining of crude-oil for own consumption in combustion plants with a total rated thermal input not exceeding 500 MW which were granted a permit before 27 November 2002 or where a complete application for a permit was submitted before that date, provided that the plant was put into operation no later than 27 November 2003.	(1)The emission limit value is 450 mg/Nm³ for the firing of distillation and conversion residues from the refining of crude-oil for own consumption in combustion plants with a total rated thermal input not exceeding 500 MW which were granted a permit before 27 November 2002 or where a complete application for a permit was submitted before that date, provided that the plant was put into operation no later than 27 November 2003.	(1)The emission limit value is 450 mg/Nm³ for the firing of distillation and conversion residues from the refining of crude-oil for own consumption in combustion plants with a total rated thermal input not exceeding 500 MW which were granted a permit before 27 November 2002 or where a complete application for a permit was submitted before that date, provided that the plant was put into operation no later than 27 November 2003.
500-100	300450 in case of pulverised lignite combustion	300	450
100-300	200	250	200[^f01032]
>300	200	200	150[^f01032]

(2) Combustion plants in chemical installations using liquid production residues as non-commercial fuel for own consumption with a total rated thermal input not exceeding 500 MW which were granted a permit before 27 November 2002 or where a complete application for a permit was submitted before that date, provided that the plant was put into operation no later than 27 November 2003, are subject to an emission limit value for NOx of 450 mg/Nm³.

(3) Combustion plants using solid or liquid fuels with a total rated thermal input not exceeding 500 MW which were granted a permit before 27 November 2002 or where a complete application for a permit was submitted before that date, provided that the plant was put into operation no later than 27 November 2003, and which do not operate more than 1,500 operating hours per year as a rolling average over a period of 5 years, are subject to an emission limit value for NOx of 450 mg/Nm³.

(4) Combustion plants using solid fuels with a total rated thermal input greater than 500 MW, which were granted a permit before 1 July 1987 and which do not operate more than 1,500 operating hours per year as a rolling average over a period of 5 years, are subject to an emission limit value for NOx of 450 mg/Nm³.

(5) Combustion plants using liquid fuels, with a total rated thermal input greater than 500 MW which were granted a permit before 27 November 2002 or where a complete application for a permit was submitted before that date, provided that the plant was put into operation no later than 27 November 2003, and which do not operate more than 1,500 operating hours per year as a rolling average over a period of 5 years, are subject to an emission limit value for NOx of 400 mg/Nm³.

(6) A part of a combustion plant discharging its waste gases through one or more separate flues within a common stack, and which does not operate more than 1,500 operating hours per year as a rolling average over a period of 5 years, may be subject to the emission limit values set out in sub-paragraphs (3) to (5) in relation to the total rated thermal input of the entire combustion plant.

(7) Where sub-paragraph (6) applies, the emissions through each of those flues must be monitored separately.

Emission limit values for gas turbines using light and middle distillates as liquid fuels

20

(1) Gas turbines (including CCGT) using light and middle distillates as liquid fuels are subject to an emission limit value for NOx of 90 mg/Nm³ and for CO of 100 mg/Nm³ unless the circumstances in sub-paragraph (2) apply.

(2) Gas turbines for emergency use that operate less than 500 operating hours per year are not covered by the emission limit values set out in this paragraph.

Emission limit values for NOx and CO for gas fired combustion plants

21

(1) The emission limit values (mg/Nm³) for NOx and CO for gas fired combustion plants, unless the circumstances in sub-paragraphs (2) to (4) apply are as set out in Table 4—

	NOx	CO
(1)Natural gas is naturally occurring methane with not more than 20% (by volume) of inerts and other constituents.	(1)Natural gas is naturally occurring methane with not more than 20% (by volume) of inerts and other constituents.	(1)Natural gas is naturally occurring methane with not more than 20% (by volume) of inerts and other constituents.
(2)75 mg/Nm³ in the following cases, where the efficiency of the gas turbine is determined at ISO baseload conditions:	(2)75 mg/Nm³ in the following cases, where the efficiency of the gas turbine is determined at ISO baseload conditions:	(2)75 mg/Nm³ in the following cases, where the efficiency of the gas turbine is determined at ISO baseload conditions:
(i) gas turbines, used in combined heat and power systems having an overall efficiency greater than 75%,	(i) gas turbines, used in combined heat and power systems having an overall efficiency greater than 75%,	(i) gas turbines, used in combined heat and power systems having an overall efficiency greater than 75%,
(ii) gas turbines used in combined cycle plants having an annual average overall electrical efficiency greater than 55%,	(ii) gas turbines used in combined cycle plants having an annual average overall electrical efficiency greater than 55%,	(ii) gas turbines used in combined cycle plants having an annual average overall electrical efficiency greater than 55%,
(iii) gas turbines for mechanical drives.	(iii) gas turbines for mechanical drives.	(iii) gas turbines for mechanical drives.
(3)For single cycle gas turbines not falling into any of the categories mentioned under note (2) but having an efficiency greater than 35% – determined at ISO base load conditions – the emission limit value for NOx is 50xη/35 where η is the gas turbine efficiency at ISO base load conditions expressed as a percentage.	(3)For single cycle gas turbines not falling into any of the categories mentioned under note (2) but having an efficiency greater than 35% – determined at ISO base load conditions – the emission limit value for NOx is 50xη/35 where η is the gas turbine efficiency at ISO base load conditions expressed as a percentage.	(3)For single cycle gas turbines not falling into any of the categories mentioned under note (2) but having an efficiency greater than 35% – determined at ISO base load conditions – the emission limit value for NOx is 50xη/35 where η is the gas turbine efficiency at ISO base load conditions expressed as a percentage.
(4)300 mg/Nm³ for such combustion plants with a total rated thermal input not exceeding 500 MW which were granted a permit before 27 November 2002 or the operators of which had submitted a complete application for a permit before that date, provided that the plant was put into operation no later than 27 November 2003.	(4)300 mg/Nm³ for such combustion plants with a total rated thermal input not exceeding 500 MW which were granted a permit before 27 November 2002 or the operators of which had submitted a complete application for a permit before that date, provided that the plant was put into operation no later than 27 November 2003.	(4)300 mg/Nm³ for such combustion plants with a total rated thermal input not exceeding 500 MW which were granted a permit before 27 November 2002 or the operators of which had submitted a complete application for a permit before that date, provided that the plant was put into operation no later than 27 November 2003.
Combustion plants firing natural gas with the exception of gas turbines and gas engines	100	100
Combustion plants firing blast furnace gas, coke oven gas or low calorific gases from gasification of refinery residues, with the exception of gas turbines and gas engines	200[^f01039]	_
Combustion plants firing other gases, with the exception of gas turbines and gas engines	200[^f01039]	_
Gas turbines (including CCGT), using natural gas[^f01033] as fuel	50[^f01034][^f01038]	100
Gas turbines (including CCGT), using other gases as fuel	120	_
Gas engines	100	100

(2) For gas turbines (including CCGT), the NOx and CO emission limit values set out in the table contained in this paragraph apply only above 70% load.

(3) For gas turbines (including CCGT) which were granted a permit before 27 November 2002 or where a complete application for a permit was submitted before that date, provided that the plant was put into operation no later than 27 November 2003, and which do not operate more than 1,500 operating hours per year as a rolling average over a period of 5 years, the emission limit value for NOx is 150 mg/Nm³ when firing natural gas and 200 mg/Nm³ when firing other gases or liquid fuels.

(4) A part of a combustion plant discharging its waste gases through one or more separate flues within a common stack, and which does not operate more than 1,500 operating hours per year as a rolling average over a period of 5 years, may be subject to the emission limit values set out in sub-paragraphs (2) and (3) in relation to the total rated thermal input of the entire combustion plant.

(5) Where sub-paragraph (4) applies, the emissions through each of those flues must be monitored separately.

(6) Gas turbines and gas engines for emergency use that operate less than 500 operating hours per year are not covered by the emission limit values set out in this paragraph.

Emission limit values for dust for combustion plants using solid or liquid fuels (except gas turbines and gas engines)

22

Emission limit values (mg/Nm³) for dust for combustion plants using solid or liquid fuels with the exception of gas turbines and gas engines are as set out in Table 5—

Total rated thermal input (MW)	Coal and lignite and other solid fuels	Biomass and peat	Liquid fuels[^f01040]
(1)The emission limit value is 50 mg/Nm³ for the firing of distillation and conversion residues from the refining of crude oil for own consumption in combustion plants which were granted a permit before 27 November 2002 or where a complete application for a permit was submitted before that date, provided that the plant was put into operation no later than 27 November 2003.	(1)The emission limit value is 50 mg/Nm³ for the firing of distillation and conversion residues from the refining of crude oil for own consumption in combustion plants which were granted a permit before 27 November 2002 or where a complete application for a permit was submitted before that date, provided that the plant was put into operation no later than 27 November 2003.	(1)The emission limit value is 50 mg/Nm³ for the firing of distillation and conversion residues from the refining of crude oil for own consumption in combustion plants which were granted a permit before 27 November 2002 or where a complete application for a permit was submitted before that date, provided that the plant was put into operation no later than 27 November 2003.	(1)The emission limit value is 50 mg/Nm³ for the firing of distillation and conversion residues from the refining of crude oil for own consumption in combustion plants which were granted a permit before 27 November 2002 or where a complete application for a permit was submitted before that date, provided that the plant was put into operation no later than 27 November 2003.
50-100	30	30	30
100-300	25	20	25
>300	20	20	20

Emission limit values for dust for combustion plants using gaseous fuels (except gas turbines and gas engines)

23

Emission limit values (mg/Nm³) for dust for combustion plants using gaseous fuels with the exception of gas turbines and gas engines are as set out in Table 6—

In general	5
Blast furnace gas	10
Gases produced by the steel industry which can be used elsewhere	30

CHAPTER2 — Emission limit values for combustion plants referred to in paragraphs 7(2) and 7(3)

Calculation of emission limit values

24

(1) All emission limit values are to be calculated—

(a) at a temperature of 273.15K,

(b) a pressure of 101.3kPa,

(d) at a standardised O₂ content of—

(i) 6% for solid fuels,

(ii) 3% for combustion plants other than gas turbines and gas engines using liquid and gaseous fuels,

(iii) 15% for gas turbines and gas engines.

(2) In case of combined cycle gas turbines with supplementary firing, the standardised O₂ content may be defined by SEPA, taking into account the specific characteristics of the installation concerned.

Emission limit values for SO2 combustion plants using solid or liquid fuels (except gas turbines and gas engines)

25

Emission limit values (mg/Nm³) for SO₂ for combustion plants using solid or liquid fuels with the exception of gas turbines and gas engines are as set out in Table 7—

Total rated thermal input (MW)	Coal and lignite and other solid fuels	Biomass	Peat	Liquid fuels
50-100	400	200	300	350
100-300	200	200	300250 in case of fluidised bed combustion	200
>300	150200 in case of circulating or pressurised fluidised bed combustion	150	150200 in case of fluidised bed combustion	150

Emission limit values for SO2 combustion plants using gaseous fuels (except gas turbines and gas engines)

26

Emission limit values (mg/Nm³) for SO₂ for combustion plants using gaseous fuels with the exception of gas turbines and gas engines are as set out in Table 8—

In general	35
Liquified gas	5
Low calorific gases from coke oven	400
Low calorific gases from blast furnace	200

Emission limit values for NOx for combustion plants using solid or liquid fuels (except gas turbines and gas engines)

27

Emission limit values (mg/Nm³) for NOx for combustion plants using solid or liquid fuels with the exception of gas turbines and gas engines are as set out in Table 9—

Total rated thermal input (MW)	Coal and lignite and other solid fuels	Biomass and peat	Liquid fuels
50-100	300400 in case of pulverisedlignite combustion	250	300
100-300	200	200	150
>300	150200 in case of pulverisedlignite combustion	150	100

Emission limit values for NOx and CO for gas turbines (including CCGT) using middle and light distillates as liquid fuels

28

(1) Gas turbines (including CCGT) using light and middle distillates as liquid fuels are subject to an emission limit value for NOx of 50 mg/Nm³ and for CO of 100 mg/Nm³.

(2) Gas turbines for emergency use that operate less than 500 operating hours per year are not covered by the emission limit values set out in this paragraph.

29

(1) Emission limit values (mg/Nm³) for NOx and CO for gas fired combustion plants are as set out in Table 10—

	NOx	CO
(1)For single cycle gas turbines having an efficiency greater than 35% – determined at ISO base load conditions – the emission limit value for NOx is 50xη/35 where η is the gas turbine efficiency at ISO base load conditions expressed as a percentage.	(1)For single cycle gas turbines having an efficiency greater than 35% – determined at ISO base load conditions – the emission limit value for NOx is 50xη/35 where η is the gas turbine efficiency at ISO base load conditions expressed as a percentage.	(1)For single cycle gas turbines having an efficiency greater than 35% – determined at ISO base load conditions – the emission limit value for NOx is 50xη/35 where η is the gas turbine efficiency at ISO base load conditions expressed as a percentage.
Combustion plants other than gas turbinesand gas engines	100	100
Gas turbines (including CCGT)	50[^f01041]	100
Gas engines	75	100

(2) For gas turbines (including CCGT), the NOx and CO emission limit values set out in this point apply only above 70% load.

(3) Gas turbines and gas engines for emergency use that operate less than 500 operating hours per year are not covered by the emission limit values set out in this paragraph.

Emission limit values for dust for combustion plants using solid or liquid fuels (except gas turbines and gas engines)

30

Emission limit values (mg/Nm³) for dust for combustion plants using solid or liquid fuels with the exception of gas turbines and gas engines are as set out in Table 11—

Total rated thermal input (MW)
50-300	20
>300	1020 for biomass and peat

Emission limit values for dust for combustion plants using gaseous fuels (except gas turbines and gas engines)

31

Emission limit values (mg/Nm³) for dust for combustion plants using gaseous fuels with the exception of gas turbines and gas engines are as set out in Table 12—

In general	5
Blast furnace gas	10
Gases produced by the steel industry which can be used elsewhere	30

CHAPTER3 — Emission monitoring

Measurements

32

(1) The concentrations of SO₂, NOx and dust in waste gases from each combustion plant with a total rated thermal input of 100 MW or more must be measured continuously unless sub-paragraph (3) applies.

(2) The concentration of CO in waste gases from each combustion plant firing gaseous fuels with a total rated thermal input of 100 MW or more must be measured continuously unless sub-paragraph (3) applies.

(3) SEPA may elect not to require the continuous measurements required by sub-paragraphs (1) and (2) in the following cases—

(a) for combustion plants with a life span of less than 10,000 operational hours,

(b) for SO₂ and dust from combustion plants firing natural gas,

(c) for SO₂ from combustion plants firing oil with known sulphur content in cases where there is no waste gas desulphurisation equipment,

(d) for SO₂ from combustion plants firing biomass if the operator can prove that the SO₂ emissions can under no circumstances be higher than the prescribed emission limit values,

(4) where SEPA does not require continuous measurements, measurements of dust and, for gas fired plants, CO are required at least once every 6 months,

(5) where SEPA does not require continuous measurements, measurements of SO₂ andNOx are—

(a) required at least once every 6 months, unless head (b) applies,

(b) this sub-paragraph applies where SEPA has verified and approved of other procedures to determine SO₂ and NOx emissions,

(i) use relevant CEN standards or British standards,

(ii) when relevant CEN or British standards are not available, ISO or other international standards which ensure the provision of data of an equivalent scientific quality.

(6) For combustion plants firing coal or lignite, the emissions of total mercury must be measured at least once per year.

Changes in fuel used or mode of operation of the plant

33

(1) SEPA must be informed of significant changes in the type of fuel used or in the mode of operation of the plant.

(2) Where informed of a significant change in accordance with sub-paragraph (1), SEPA must decide whether the monitoring requirements in paragraph 32(1) to (4) and (6) of this schedule are still adequate or require to be adjusted.

Measurement of oxygen content, temperature, pressure and water vapour content of waste gases

34

(1) Continuous measurements carried out in accordance with paragraph 32(1) and (2) of this schedule must include the measurement of the oxygen content, temperature, pressure and water vapour content of the waste gases unless sub-paragraph (2) applies.

(2) The continuous measurement of the water vapour content of the waste gases is not necessary where the sampled waste gas is dried before the emissions are analysed.

Relevant standards

35

(1) The following procedures must be carried out in accordance with relevant CEN or British standards, or where those are not available, ISO or other international standards which ensure the provision of data of an equivalent scientific quality—

(a) sampling and analysis of relevant polluting substances,

(b) measurements of process parameters,

(2) Automated measuring systems must also be subject to control by means of parallel measurements with the reference methods at least once per year.

Confident interval values

36

At the emission limit value level, the values of the 95% confidence intervals of a single measured result must not exceed the following percentages of the emission limit values—

(a) carbon monoxide 10%,

(b) sulphur dioxide 20%,

(d) dust 30%.

Validated hourly and daily averages

37

(1) The validated hourly and daily average values are to be determined from the measured valid hourly average values after having subtracted the value of the confidence interval specified in paragraph 36 of this schedule.

(2) Any day in which more than three hourly average values are invalid due to malfunction or maintenance of the automated measuring system must be invalidated.

Sulphur content

38

Where plants are required to comply with the rates of desulphurisation in paragraph 9 of this schedule, the sulphur content of the fuel which is fired in the combustion plant must also be regularly monitored.

CHAPTER4 — Assessment of compliance with emission limit values

39

(1) For continuous measurements, the emission limit values set out in Chapters 1 and 2 of this schedule are to be regarded as having been complied with if the evaluation of the measurement results indicates, for operating hours within a calendar year, that all of the following conditions have been met—

(a) no validated monthly average value exceeds the relevant emission limit values set out in Chapters 1 and 2 of this schedule,

(b) no validated daily average value exceeds 110% of the relevant emission limit values set out in Chapters 1 and 2 of this schedule,

(c) in cases of combustion plants composed only of boilers using coal with a total rated thermal input below 50 MW, no validated daily average value exceeds 150% of the relevant emission limit values set out in Chapters 1 and 2 of this schedule,

(d) 95% of all the validated hourly average values over the year do not exceed 200% of the relevant emission limit values set out in Chapters 1 and 2 of this schedule,

(e) validated average values are determined as set out in paragraph 37 of this schedule,

(f) for the purpose of the calculation of the average emission values, the values measured during the periods referred to in paragraphs 8 and 11 of this schedule as well as during the start-up and shut-down periods are to be disregarded.

(2) Where continuous measurements are not required, the emission limit values set out in Chapters 1 and 2 of this schedule are to be regarded as having been complied with if the results of each of the series of measurements or of the other procedures defined and determined according to the rules laid down by SEPA do not exceed the emission limit values.

CHAPTER5 — Minimum rate of desulphurisation

40

Minimum rate of desulphurisation for combustion plants referred to in paragraphs 6(1) and (2) of this schedule is as stated in Table 13—

	Minimum rate ofdesulphurisation	Minimum rate ofdesulphurisation
(1)For combustion plants firing oil shale, the minimum rate of desulphurisation is 95%	(1)For combustion plants firing oil shale, the minimum rate of desulphurisation is 95%	(1)For combustion plants firing oil shale, the minimum rate of desulphurisation is 95%
Total rated thermal input (MW)	Plants which were granted a permit before27 November 2002 or those where a complete application for a permit was submitted beforethat date, provided that the plant was put intooperation no later than 27 November 2003	Other plants
50-100	80%	92%
100-300	90%	92%
>300	96%[^f01042]	96%

41

The minimum rate of desulphurisation for combustion plants referred to in paragraph 6(3) of this schedule are as set out in Table 14—

Total rated thermal input (MW)	Minimum rate of desulphurisation
50—100	93%
100-300	93%
>300	97%

42

The minimum rates of desulphurisation set out in this Chapter apply as a monthly average limit value.

CHAPTER6 — Average emission limit values for multi-fuel combustion plants within a refinery

43

(1) Average emission limit values (mg/Nm³) for SO₂ for multi-fuel firing combustion plants within a refinery, with the exception of gas turbines and gas engines, which use the distillation and conversion residues from the refining of crude-oil for own consumption, alone or with other fuels—

(a) for combustion plants which were granted a permit before 27 November 2002 or the operators of which had submitted a complete application for a permit before that date, provided that the plant was put into operation no later than 27 November 2003 is 1000 mg/Nm³,

(b) for other combustion plants: 600 mg/Nm³.

(2) These emission limit values are to be calculated at—

(a) a temperature of 273.15K,

(b) a pressure of 101.3kPa,

(d) at a standardised O₂ content of—

(i) 6% for solid fuels,

(ii) 3% for liquid and gaseous fuels.

SCHEDULE22 — INCINERATION AND CO-INCINERATION OF WASTE AT A WASTE INCINERATION PLANT OR WASTE CO-INCINERATION PLANT

PART1 — Scope and Interpretation

Scope

1

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