Commission Implementing Decision (EU) 2017/1442 of 31 July 2017 establishing best available techniques (BAT) conclusions, under Directive 2010/75/EU of the European Parliament and of the Council, for large combustion plants (notified under document C(2017) 5225) (Text with EEA relevance. )

Biomass/peat

• LHV

• moisture

• Ash

• C, Cl, F, N, S, K, Na

• Metals and metalloids (As, Cd, Cr, Cu, Hg, Pb, Zn)

Coal/lignite

• LHV

• Moisture

• Volatiles, ash, fixed carbon, C, H, N, O, S

• Br, Cl, F

• Metals and metalloids (As, Cd, Co, Cr, Cu, Hg, Mn, Ni, Pb, Sb, Tl, V, Zn)

HFO

• Ash

• C, S, N, Ni, V

Gas oil

• Ash

• N, C, S

Natural gas

• LHV

• CH4, C2H6, C3, C4+, CO2, N2, Wobbe index

Process fuels from the chemical industry⁽¹⁾

• Br, C, Cl, F, H, N, O, S

• Metals and metalloids (As, Cd, Co, Cr, Cu, Hg, Mn, Ni, Pb, Sb, Tl, V, Zn)

Iron and steel process gases

• LHV, CH4 (for COG), CXHY (for COG), CO2, H2, N2, total sulphur, dust, Wobbe index

Waste⁽²⁾

• LHV

• Moisture

• Volatiles, ash, Br, C, Cl, F, H, N, O, S

• Metals and metalloids (As, Cd, Co, Cr, Cu, Hg, Mn, Ni, Pb, Sb, Tl, V, Zn)

a.

Integrated combustion process ensuring high boiler efficiency and including primary techniques for NOX reduction (e.g. air staging, fuel staging, low-NOX burners (LNB) and/or flue-gas recirculation)

Combustion processes such as pulverised combustion, fluidised bed combustion or moving grate firing allow this integration

Generally applicable

a.

Dry bottom ash handling

Dry hot bottom ash falls from the furnace onto a mechanical conveyor system and, after redirection to the furnace for reburning, is cooled down by ambient air. Useful energy is recovered from both the ash reburning and ash cooling

There may be technical restrictions that prevent retrofitting to existing combustion units

Coal-fired, ≥ 1 000 MWth

45 – 46

33,5 – 44

75 – 97

Lignite-fired, ≥ 1 000 MWth

42 – 44⁽⁹⁾

33,5 – 42,5

75 – 97

Coal-fired, < 1 000 MWth

36,5 – 41,5⁽¹⁰⁾

32,5 – 41,5

75 – 97

Lignite-fired, < 1 000 MWth

36,5 – 40⁽¹¹⁾

31,5 – 39,5

75 – 97

a.

Combustion optimisation

See description in Section 8.3.

Generally used in combination with other techniques

Generally applicable

b.

Combination of other primary techniques for NOX reduction (e.g. air staging, fuel staging, flue-gas recirculation, low-NOX burners (LNB))

See description in Section 8.3 for each single technique.

The choice and performance of (an) appropriate (combination of) primary techniques may be influenced by the boiler design

c.

Selective non-catalytic reduction (SNCR)

See description in Section 8.3.

Can be applied with ‘slip’ SCR

The applicability may be limited in the case of boilers with a high cross-sectional area preventing homogeneous mixing of NH3 and NOX.

The applicability may be limited in the case of combustion plants operated < 1 500 h/yr with highly variable boiler loads

d.

Selective catalytic reduction (SCR)

See description in Section 8.3

Not applicable to combustion plants of < 300 MWth operated < 500 h/yr.

Not generally applicable to combustion plants of < 100 MWth.

There may be technical and economic restrictions for retrofitting existing combustion plants operated between 500 h/yr and 1 500 h/yr and for existing combustion plants of ≥ 300 MWth operated < 500 h/yr

e.

Combined techniques for NOX and SOX reduction

See description in Section 8.3

Applicable on a case-by-case basis, depending on the fuel characteristics and combustion process

< 100

100–150

100–270

155–200

165–330

100–300

50–100

100–180

80–130

155–210

≥ 300, FBC boiler combusting coal and/or lignite and lignite-fired PC boiler

50 – 85

< 85 – 150^{(4) (5)}

80 – 125

140 – 165⁽⁶⁾

≥ 300, coal-fired PC boiler

65 – 85

65 – 150

80 – 125

< 85 – 165⁽⁷⁾

< 300

< 30–140

≥ 300, FBC boiler combusting coal and/or lignite and lignite-fired PC boiler

< 30–100⁽¹⁾

≥ 300, coal-fired PC boiler

< 5–100⁽¹⁾

a.

Boiler sorbent injection (in-furnace or in-bed)

See description in Section 8.4

Generally applicable

b.

Duct sorbent injection (DSI)

See description in Section 8.4.

The technique can be used for HCl/HF removal when no specific FGD end-of-pipe technique is implemented

c.

Spray dry absorber (SDA)

See description in Section 8.4

d.

Circulating fluidised bed (CFB) dry scrubber

e.

Wet scrubbing

See description in Section 8.4.

The techniques can be used for HCl/HF removal when no specific FGD end-of-pipe technique is implemented

f.

Wet flue-gas desulphurisation (wet FGD)

See description in Section 8.4

Not applicable to combustion plants operated < 500 h/yr.

There may be technical and economic restrictions for applying the technique to combustion plants of < 300 MWth, and for retrofitting existing combustion plants operated between 500 h/yr and 1 500 h/yr

g.

Seawater FGD

h.

Combined techniques for NOX and SOX reduction

Applicable on a case-by-case basis, depending on the fuel characteristics and combustion process

i.

Replacement or removal of the gas-gas heater located downstream of the wet FGD

Replacement of the gas-gas heater downstream of the wet FGD by a multi-pipe heat extractor, or removal and discharge of the flue-gas via a cooling tower or a wet stack

Only applicable when the heat exchanger needs to be changed or replaced in combustion plants fitted with wet FGD and a downstream gas-gas heater

j.

Fuel choice

See description in Section 8.4.

Use of fuel with low sulphur (e.g. down to 0,1 wt-%, dry basis), chlorine or fluorine content

Applicable within the constraints associated with the availability of different types of fuel, which may be impacted by the energy policy of the Member State. The applicability may be limited due to design constraints in the case of combustion plants combusting highly specific indigenous fuels

< 100

150–200

150–360

170–220

170–400

100–300

80–150

95–200

135–200

135–220⁽³⁾

≥ 300, PC boiler

10–75

10–130⁽⁴⁾

25–110

25–165⁽⁵⁾

≥ 300, Fluidised bed boiler⁽⁶⁾

20–75

20–180

25–110

50–220

HCl

< 100

1–6

2–10⁽²⁾

≥ 100

1–3

1–5^{(2) (3)}

HF

< 100

< 1–3

< 1–6⁽⁴⁾

≥ 100

< 1–2

< 1–3⁽⁴⁾

a.

Electrostatic precipitator (ESP)

See description in Section 8.5

Generally applicable

b.

Bag filter

c.

Boiler sorbent injection

(in-furnace or in-bed)

See descriptions in Section 8.5.

The techniques are mainly used for SOX, HCl and/or HF control

d.

Dry or semi-dry FGD system

e.

Wet flue-gas desulphurisation (wet FGD)

See applicability in BAT 21

< 100

2–5

2–18

4–16

4–22⁽³⁾

100–300

2–5

2–14

3–15

4–22⁽⁴⁾

300–1 000

2–5

2–10⁽⁵⁾

3–10

3–11⁽⁶⁾

≥ 1 000

2–5

2–8

3–10

3–11⁽⁷⁾

a.

Electrostatic precipitator (ESP)

See description in Section 8.5.

Higher mercury removal efficiency is achieved at flue-gas temperatures below 130 °C.

The technique is mainly used for dust control

Generally applicable

b.

Bag filter

See description in Section 8.5.

The technique is mainly used for dust control

c.

Dry or semi-dry FGD system

See descriptions in Section 8.5.

The techniques are mainly used for SOX, HCl and/or HF control

d.

Wet flue-gas desulphurisation (wet FGD)

See applicability in BAT 21

e.

Selective catalytic reduction (SCR)

See description in Section 8.3.

Only used in combination with other techniques to enhance or reduce the mercury oxidation before capture in a subsequent FGD or dedusting system.

The technique is mainly used for NOX control

See applicability in BAT 20

f.

Carbon sorbent (e.g. activated carbon or halogenated activated carbon) injection in the flue-gas

See description in Section 8.5.

Generally used in combination with an ESP/bag filter. The use of this technique may require additional treatment steps to further segregate the mercury-containing carbon fraction prior to further reuse of the fly ash

Generally applicable

g.

Use of halogenated additives in the fuel or injected in the furnace

See description in Section 8.5

Generally applicable in the case of a low halogen content in the fuel

h.

Fuel pretreatment

Fuel washing, blending and mixing in order to limit/reduce the mercury content or improve mercury capture by pollution control equipment

Applicability is subject to a previous survey for characterising the fuel and for estimating the potential effectiveness of the technique

i.

Fuel choice

See description in Section 8.5

Applicable within the constraints associated with the availability of different types of fuel, which may be impacted by the energy policy of the Member State

< 300

< 1–3

< 1–5

< 1–9

< 1–10

≥ 300

< 1–2

< 1–4

< 1–4

< 1–7

Solid biomass and/or peat boiler

33,5–to > 38

28–38

73–99

73–99

a.

Combustion optimisation

See descriptions in Section 8.3

Generally applicable

b.

Low-NOX burners (LNB)

c.

Air staging

d.

Fuel staging

e.

Flue-gas recirculation

f.

Selective non-catalytic reduction (SNCR)

See description in Section 8.3.

Can be applied with ‘slip’ SCR

Not applicable to combustion plants operated < 500 h/yr with highly variable boiler loads.

The applicability may be limited in the case of combustion plants operated between 500 h/yr and 1 500 h/yr with highly variable boiler loads.

For existing combustion plants, applicable within the constraints associated with the required temperature window and residence time for the injected reactants

g.

Selective catalytic reduction (SCR)

See description in Section 8.3.

The use of high-alkali fuels (e.g. straw) may require the SCR to be installed downstream of the dust abatement system

Not applicable to combustion plants operated < 500 h/yr.

There may be economic restrictions for retrofitting existing combustion plants of < 300 MWth.

Not generally applicable to existing combustion plants of < 100 MWth

50–100

70–150⁽³⁾

70–225⁽⁴⁾

120–200⁽⁵⁾

120–275⁽⁶⁾

100–300

50–140

50–180

100–200

100–220

≥ 300

40–140

40–150⁽⁷⁾

65–150

95–165⁽⁸⁾

a.

Boiler sorbent injection (in-furnace or in-bed)

See descriptions in Section 8.4

Generally applicable

b.

Duct sorbent injection (DSI)

c.

Spray dry absorber (SDA)

d.

Circulating fluidised bed (CFB) dry scrubber

e.

Wet scrubbing

f.

Flue-gas condenser

g.

Wet flue-gas desulphurisation (wet FGD)

Not applicable to combustion plants operated < 500 h/yr.

There may be technical and economic restrictions for retrofitting existing combustion plants operated between 500 h/yr and 1 500 h/yr

h.

Fuel choice

Applicable within the constraints associated with the availability of different types of fuel, which may be impacted by the energy policy of the Member State

< 100

15–70

15–100

30–175

30–215

100–300

< 10–50

< 10–70⁽³⁾

< 20–85

< 20–175⁽⁴⁾

≥ 300

< 10–35

< 10–50⁽³⁾

< 20–70

< 20–85⁽⁵⁾

< 100

1–7

1–15

1–12

1–35

< 1

< 1,5

100–300

1–5

1–9

1–12

1–12

< 1

< 1

≥ 300

1–5

1–5

1–12

1–12

< 1

< 1

a.

Electrostatic precipitator (ESP)

See description in Section 8.5

Generally applicable

b.

Bag filter

c.

Dry or semi-dry FGD system

See descriptions in Section 8.5

The techniques are mainly used for SOX, HCl and/or HF control

d.

Wet flue-gas desulphurisation (wet FGD)

See applicability in BAT 25

e.

Fuel choice

See description in Section 8.5

Applicable within the constraints associated with the availability of different types of fuel, which may be impacted by the energy policy of the Member State

< 100

2–5

2–15

2–10

2–22

100–300

2–5

2–12

2–10

2–18

≥ 300

2–5

2–10

2–10

2–16

a.

Carbon sorbent (e.g. activated carbon or halogenated activated carbon) injection in the flue-gas

See descriptions in Section 8.5

Generally applicable

b.

Use of halogenated additives in the fuel or injected in the furnace

Generally applicable in the case of a low halogen content in the fuel

c.

Fuel choice

Applicable within the constraints associated with the availability of different types of fuel, which may be impacted by the energy policy of the Member State

d.

Electrostatic precipitator (ESP)

See descriptions in Section 8.5.

The techniques are mainly used for dust control

Generally applicable

e.

Bag filter

f.

Dry or semi-dry FGD system

See descriptions in Section 8.5.

The techniques are mainly used for SOX, HCl and/or HF control

g.

Wet flue-gas desulphurisation (wet FGD)

See applicability in BAT 25

HFO- and/or gas-oil-fired boiler

> 36,4

35,6–37,4

80–96

80–96

a.

Air staging

See descriptions in Section 8.3

Generally applicable

b.

Fuel staging

c.

Flue-gas recirculation

d.

Low-NOX burners (LNB)

e.

Water/steam addition

Applicable within the constraints of water availability

f.

Selective non-catalytic reduction (SNCR)

Not applicable to combustion plants operated < 500 h/yr with highly variable boiler loads.

The applicability may be limited in the case of combustion plants operated between 500 h/yr and 1 500 h/yr with highly variable boiler loads

g.

Selective catalytic reduction (SCR)

See descriptions in Section 8.3

Not applicable to combustion plants operated < 500 h/yr.

There may be technical and economic restrictions for retrofitting existing combustion plants operated between 500 h/yr and 1 500 h/yr.

Not generally applicable to combustion plants of < 100 MWth

h.

Advanced control system

Generally applicable to new combustion plants. The applicability to old combustion plants may be constrained by the need to retrofit the combustion system and/or control command system

i.

Fuel choice

Applicable within the constraints associated with the availability of different types of fuel, which may be impacted by the energy policy of the Member State

< 100

75–200

150–270

100–215

210–330⁽³⁾

≥ 100

45–75

45–100⁽⁴⁾

85–100

85–110^{(5) (6)}

a.

Duct sorbent injection (DSI)

See description in Section 8.4

Generally applicable

b.

Spray dry absorber (SDA)

c.

Flue-gas condenser

d.

Wet flue-gas desulphurisation

(wet FGD)

There may be technical and economic restrictions for applying the technique to combustion plants of < 300 MWth.

Not applicable to combustion plants operated < 500 h/yr.

There may be technical and economic restrictions for retrofitting existing combustion plants operated between 500 h/yr and 1 500 h/yr

e.

Seawater FGD

There may be technical and economic restrictions for applying the technique to combustion plants of < 300 MWth.

Not applicable to combustion plants operated < 500 h/yr.

There may be technical and economic restrictions for retrofitting existing combustion plants operated between 500 h/yr and 1 500 h/yr

f.

Fuel choice

Applicable within the constraints associated with the availability of different types of fuel, which may be impacted by the energy policy of the Member State

< 300

50–175

50–175

150–200

150–200⁽³⁾

≥ 300

35–50

50–110

50–120

150–165^{(4) (5)}

a.

Electrostatic precipitator (ESP)

See description in Section 8.5

Generally applicable

b.

Bag filter

c.

Multicyclones

See description in Section 8.5.

Multicyclones can be used in combination with other dedusting techniques

d.

Dry or semi-dry FGD system

See descriptions in Section 8.5.

The technique is mainly used for SOX, HCl and/or HF control

e.

Wet flue-gas desulphurisation (wet FGD)

See description in Section 8.5.

The technique is mainly used for SOX, HCl and/or HF control

See applicability in BAT 29

f.

Fuel choice

See description in Section 8.5

Applicable within the constraints associated with the availability of different types of fuel, which may be impacted by the energy policy of the Member State

< 300

2–10

2–20

7–18

7–22⁽³⁾

≥ 300

2–5

2–10

7–10

7–11⁽⁴⁾

a.

Combined cycle

See description in Section 8.2

Generally applicable to new units operated ≥ 1 500 h/yr.

Applicable to existing units within the constraints associated with the steam cycle design and the space availability.

Not applicable to existing units operated < 1 500 h/yr

HFO- and/or gas-oil-fired reciprocating engine — single cycle

41,5–44,5⁽³⁾

38,3–44,5⁽³⁾

HFO- and/or gas-oil-fired reciprocating engine — combined cycle

> 48⁽⁴⁾

No BAT-AEEL

a.

Low-NOX combustion concept in diesel engines

See descriptions in Section 8.3

Generally applicable

b.

Exhaust-gas recirculation (EGR)

Not applicable to four-stroke engines

c.

Water/steam addition

Applicable within the constraints of water availability.

The applicability may be limited where no retrofit package is available

d.

Selective catalytic reduction (SCR)

Not applicable to combustion plants operated < 500 h/yr.

There may be technical and economic restrictions for retrofitting existing combustion plants operated between 500 h/yr and 1 500 h/yr.

Retrofitting existing combustion plants may be constrained by the availability of sufficient space

a.

Combustion optimisation

Generally applicable

b.

Oxidation catalysts

See descriptions in Section 8.3

Not applicable to combustion plants operated < 500 h/yr.

The applicability may be limited by the sulphur content of the fuel

≥ 50

115–190⁽⁴⁾

125–625

145–300

150–750

a.

Fuel choice

See descriptions in Section 8.4

Applicable within the constraints associated with the availability of different types of fuel, which may be impacted by the energy policy of the Member State

b.

Duct sorbent injection (DSI)

There may be technical restrictions in the case of existing combustion plants

Not applicable to combustion plants operated < 500 h/yr

c.

Wet flue-gas desulphurisation (wet FGD)

There may be technical and economic restrictions for applying the technique to combustion plants of < 300 MWth.

Not applicable to combustion plants operated < 500 h/yr.

There may be technical and economic restrictions for retrofitting existing combustion plants operated between 500 h/yr and 1 500 h/yr

All sizes

45–100

100–200⁽³⁾

60–110

105–235⁽³⁾

a.

Fuel choice

See descriptions in Section 8.5

Applicable within the constraints associated with the availability of different types of fuel, which may be impacted by the energy policy of the Member State

b.

Electrostatic precipitator (ESP)

Not applicable to combustion plants operated < 500 h/yr

c.

Bag filter

≥ 50

5–10

5–35

10–20

10–45

a.

Combined cycle

See description in Section 8.2

Generally applicable to new units operated ≥ 1 500 h/yr.

Applicable to existing units within the constraints associated with the steam cycle design and the space availability.

Not applicable to existing units operated < 1 500 h/yr

Gas-oil-fired open-cycle gas turbine

> 33

25–35,7

Gas-oil-fired combined cycle gas turbine

> 40

33–44

a.

Water/steam addition

See description in Section 8.3

The applicability may be limited due to water availability

b.

Low-NOX burners (LNB)

Only applicable to turbine models for which low-NOX burners are available on the market

c.

Selective catalytic reduction (SCR)

Not applicable to combustion plants operated < 500 h/yr.

There may be technical and economic restrictions for retrofitting existing combustion plants operated between 500 h/yr and 1 500 h/yr.

Retrofitting existing combustion plants may be constrained by the availability of sufficient space

a.

Combustion optimisation

See description in Section 8.3

Generally applicable

b.

Oxidation catalysts

Not applicable to combustion plants operated < 500 h/yr.

Retrofitting existing combustion plants may be constrained by the availability of sufficient space

a.

Fuel choice

See description in Section 8.4

Applicable within the constraints associated with the availability of different types of fuel, which may be impacted by the energy policy of the Member State

New and existing plants

35–60

50–66

2–5

2–10

a.

Combined cycle

See description in Section 8.2

Generally applicable to new gas turbines and engines except when operated < 1 500 h/yr.

Applicable to existing gas turbines and engines within the constraints associated with the steam cycle design and the space availability.

Not applicable to existing gas turbines and engines operated < 1 500 h/yr.

Not applicable to mechanical drive gas turbines operated in discontinuous mode with extended load variations and frequent start-ups and shutdowns.

Not applicable to boilers

Gas engine

39,5–44⁽⁶⁾

35–44⁽⁶⁾

56–85⁽⁶⁾

No BAT-AEEL.

Gas-fired boiler

39–42,5

38–40

78–95

No BAT-AEEL.

Open cycle gas turbine, ≥ 50 MWth

36–41,5

33–41,5

No BAT-AEEL

36,5–41

33,5–41

CCGT, 50–600 MWth

53–58,5

46–54

No BAT-AEEL

No BAT-AEEL

CCGT, ≥ 600 MWth

57–60,5

50–60

No BAT-AEEL

No BAT-AEEL

CHP CCGT, 50–600 MWth

53–58,5

46–54

65–95

No BAT-AEEL

CHP CCGT, ≥ 600 MWth

57–60,5

50–60

65–95

No BAT-AEEL

a.

Air and/or fuel staging

See descriptions in Section 8.3.

Air staging is often associated with low-NOX burners

Generally applicable

b.

Flue-gas recirculation

See description in Section 8.3

c.

Low-NOX burners (LNB)

d.

Advanced control system

See description in Section 8.3.

This technique is often used in combination with other techniques or may be used alone for combustion plants operated < 500 h/yr

The applicability to old combustion plants may be constrained by the need to retrofit the combustion system and/or control command system

e.

Reduction of the combustion air temperature

See description in Section 8.3

Generally applicable within the constraints associated with the process needs

f.

Selective non–catalytic reduction (SNCR)

Not applicable to combustion plants operated < 500 h/yr with highly variable boiler loads.

The applicability may be limited in the case of combustion plants operated between 500 h/yr and 1 500 h/yr with highly variable boiler loads

g.

Selective catalytic reduction (SCR)

Not applicable to combustion plants operated < 500 h/yr.

Not generally applicable to combustion plants of < 100 MWth.

There may be technical and economic restrictions for retrofitting existing combustion plants operated between 500 h/yr and 1 500 h/yr

a.

Advanced control system

See description in Section 8.3.

This technique is often used in combination with other techniques or may be used alone for combustion plants operated < 500 h/yr

The applicability to old combustion plants may be constrained by the need to retrofit the combustion system and/or control command system

b.

Water/steam addition

See description in Section 8.3

The applicability may be limited due to water availability

c.

Dry low-NOX burners (DLN)

The applicability may be limited in the case of turbines where a retrofit package is not available or when water/steam addition systems are installed

d.

Low-load design concept

Adaptation of the process control and related equipment to maintain good combustion efficiency when the demand in energy varies, e.g. by improving the inlet airflow control capability or by splitting the combustion process into decoupled combustion stages

The applicability may be limited by the gas turbine design

e.

Low-NOX burners (LNB)

See description in Section 8.3

Generally applicable to supplementary firing for heat recovery steam generators (HRSGs) in the case of combined-cycle gas turbine (CCGT) combustion plants

f.

Selective catalytic reduction (SCR)

Not applicable in the case of combustion plants operated < 500 h/yr.

Not generally applicable to existing combustion plants of < 100 MWth.

Retrofitting existing combustion plants may be constrained by the availability of sufficient space.

There may be technical and economic restrictions for retrofitting existing combustion plants operated between 500 h/yr and 1 500 h/yr

a.

Advanced control system

See description in Section 8.3.

This technique is often used in combination with other techniques or may be used alone for combustion plants operated < 500 h/yr

The applicability to old combustion plants may be constrained by the need to retrofit the combustion system and/or control command system

b.

Lean-burn concept

See description in Section 8.3.

Generally used in combination with SCR

Only applicable to new gas-fired engines

c.

Advanced lean-burn concept

See descriptions in Section 8.3

Only applicable to new spark plug ignited engines

d.

Selective catalytic reduction (SCR)

Retrofitting existing combustion plants may be constrained by the availability of sufficient space.

Not applicable to combustion plants operated < 500 h/yr.

There may be technical and economic restrictions for retrofitting existing combustion plants operated between 500 h/yr and 1 500 h/yr

New OCGT

≥ 50

15–35

25–50

Existing OCGT (excluding turbines for mechanical drive applications) — All but plants operated < 500 h/yr

≥ 50

15–50

25–55⁽⁷⁾

New CCGT

≥ 50

10–30

15–40

Existing CCGT with a net total fuel utilisation of < 75 %

≥ 600

10–40

18–50

Existing CCGT with a net total fuel utilisation of ≥ 75 %

≥ 600

10–50

18–55⁽⁹⁾

Existing CCGT with a net total fuel utilisation of < 75 %

50–600

10–45

35–55

Existing CCGT with a net total fuel utilisation of ≥ 75 %

50–600

25–50⁽¹⁰⁾

35–55⁽¹¹⁾

Gas turbine put into operation no later than 27 November 2003, or existing gas turbine for emergency use and operated < 500 h/yr

≥ 50

No BAT-AEL

60–140^{(12) (13)}

Existing gas turbine for mechanical drive applications — All but plants operated < 500 h/yr

≥ 50

15–50⁽¹⁴⁾

25–55⁽¹⁵⁾

Boiler

10–60

50–100

30–85

85–110

Engine⁽⁴⁾

20–75

20–100

55–85

55–110⁽⁵⁾

≥ 50

5–15⁽¹⁾

215–500⁽²⁾

215–560^{(1) (2)}

a.

Process gas management system

See description in Section 8.2

Only applicable to integrated steelworks

Existing multi-fuel firing gas boiler

30–40

50–84

New multi-fuel firing gas boiler⁽⁴⁾

36–42,5

50–84

CHP CCGT

> 47

40–48

60–82

CCGT

> 47

40–48

No BAT-AEEL

a.

Low-NOX burners (LNB)

See description in Section 8.3.

Specially designed low-NOX burners in multiple rows per type of fuel or including specific features for multi-fuel firing (e.g. multiple dedicated nozzles for burning different fuels, or including fuels premixing)

Generally applicable

b.

Air staging

See descriptions in Section 8.3

c.

Fuel staging

d.

Flue-gas recirculation

e.

Process gas management system

See description in Section 8.2.

Generally applicable within the constraints associated with the availability of different types of fuel

f.

Advanced control system

See description in Section 8.3.

This technique is used in combination with other techniques

The applicability to old combustion plants may be constrained by the need to retrofit the combustion system and/or control command system

g.

Selective non-catalytic reduction (SNCR)

See descriptions in Section 8.3

Not applicable to combustion plants operated < 500 h/yr

h.

Selective catalytic reduction (SCR)

Not applicable to combustion plants operated < 500 h/yr.

Not generally applicable to combustion plants of < 100 MWth.

Retrofitting existing combustion plants may be constrained by the availability of sufficient space and by the combustion plant configuration

a.

Process gas management system

See description in Section 8.2

Generally applicable within the constraints associated with the availability of different types of fuel

b.

Advanced control system

See description in Section 8.3.

This technique is used in combination with other techniques

The applicability to old combustion plants may be constrained by the need to retrofit the combustion system and/or control command system

c.

Water/steam addition

See description in Section 8.3.

In dual fuel gas turbines using DLN for the combustion of iron and steel process gases, water/steam addition is generally used when combusting natural gas

The applicability may be limited due to water availability

d.

Dry low-NOX burners(DLN)

See description in Section 8.3.

DLN that combust iron and steel process gases differ from those that combust natural gas only

Applicable within the constraints associated with the reactiveness of iron and steel process gases such as coke oven gas.

The applicability may be limited in the case of turbines where a retrofit package is not available or when water/steam addition systems are installed

e.

Low-NOX burners (LNB)

See description in Section 8.3

Only applicable to supplementary firing for heat recovery steam generators (HRSGs) of combined-cycle gas turbine (CCGT) combustion plants

f.

Selective catalytic reduction (SCR)

Retrofitting existing combustion plants may be constrained by the availability of sufficient space

a.

Combustion optimisation

See descriptions in Section 8.3

Generally applicable

b.

Oxidation catalysts

Only applicable to CCGTs.

The applicability may be limited by lack of space, the load requirements and the sulphur content of the fuel

New boiler

3

15–65

22–100

Existing boiler

3

20–100^{(2) (3)}

22–110^{(2) (4) (5)}

New CCGT

15

20–35

30–50

Existing CCGT

15

20–50^{(2) (3)}

30–55^{(5) (6)}

a.

Process gas management system and auxiliary fuel choice

See description in Section 8.2.

To the extent allowed by the iron- and steel-works, maximise the use of:

• a majority of blast furnace gas with a low sulphur content in the fuel diet,

• a combination of fuels with a low averaged sulphur content, e.g. individual process fuels with a very low S content such as:

  • Blast furnace gas with a sulphur content < 10 mg/Nm³,

  • coke oven gas with a sulphur content < 300 mg/Nm³,

• and auxiliary fuels such as:

  • natural gas,

  • liquid fuels with a sulphur content of ≤ 0,4 % (in boilers).

Use of a limited amount of fuels with a higher sulphur content

Generally applicable within the constraints associated with the availability of different types of fuel

b.

Coke oven gas pretreatment at the iron- and steel-works

Use of one of the following techniques:

• desulphurisation by absorption systems,

• wet oxidative desulphurisation

Only applicable to coke oven gas combustion plants

New or existing boiler

3

25–150

50–200⁽³⁾

New or existing CCGT

15

10–45

20–70

a.

Fuel choice/management

Use of a combination of process gases and auxiliary fuels with a low averaged dust or ash content

Generally applicable within the constraints associated with the availability of different types of fuel

b.

Blast furnace gas pretreatment at the iron- and steel-works

Use of one or a combination of dry dedusting devices (e.g. deflectors, dust catchers, cyclones, electrostatic precipitators) and/or subsequent dust abatement (venturi scrubbers, hurdle-type scrubbers, annular gap scrubbers, wet electrostatic precipitators, disintegrators)

Only applicable if blast furnace gas is combusted

c.

Basic oxygen furnace gas pretreatment at the iron- and steel-works

Use of dry (e.g. ESP or bag filter) or wet (e.g. wet ESP or scrubber) dedusting. Further descriptions are given in the Iron and Steel BREF

Only applicable if basic oxygen furnace gas is combusted

d.

Electrostatic precipitator (ESP)

See descriptions in Section 8.5

Only applicable to combustion plants combusting a significant proportion of auxiliary fuels with a high ash content

e.

Bag filter

New or existing boiler

2–7

2–10

New or existing CCGT

2–5

2–5

a.

Pretreatment of process fuel from the chemical industry

Perform fuel pretreatment on and/or off the site of the combustion plant to improve the environmental performance of fuel combustion

Applicable within the constraints associated with process fuel characteristics and space availability

Boiler using liquid process fuels from the chemical industry, including when mixed with HFO, gas oil and/or other liquid fuels

> 36,4

35,6–37,4

80–96

80–96

Boiler using gaseous process fuels from the chemical industry, including when mixed with natural gas and/or other gaseous fuels

39–42,5

38–40

78–95

78–95

a.

Low-NOX burners (LNB)

See descriptions in Section 8.3

Generally applicable

b.

Air staging

c.

Fuel staging

See description in Section 8.3.

Applying fuel staging when using liquid fuel mixtures may require a specific burner design

d.

Flue-gas recirculation

See descriptions in Section 8.3

Generally applicable to new combustion plants.

Applicable to existing combustion plants within the constraints associated with chemical installation safety

e.

Water/steam addition

The applicability may be limited due to water availability

f.

Fuel choice

Applicable within the constraints associated with the availability of different types of fuel and/or an alternative use of the process fuel

g.

Advanced control system

The applicability to old combustion plants may be constrained by the need to retrofit the combustion system and/or control command system

h.

Selective non-catalytic reduction (SNCR)

Applicable to existing combustion plants within the constraints associated with chemical installation safety.

Not applicable to combustion plants operated < 500 h/yr.

The applicability may be limited in the case of combustion plants operated between 500 h/yr and 1 500 h/yr with frequent fuel changes and frequent load variations

i.

Selective catalytic reduction (SCR)

Applicable to existing combustion plants within the constraints associated with duct configuration, space availability and chemical installation safety.

Not applicable to combustion plants operated < 500 h/yr.

There may be technical and economic restrictions for retrofitting existing combustion plants operated between 500 h/yr and 1 500 h/yr.

Not generally applicable to combustion plants of < 100 MWth

Mixture of gases and liquids

30–85

80–290⁽³⁾

50–110

100–330⁽³⁾

Gases only

20–80

70–100⁽⁴⁾

30–100

85–110⁽⁵⁾

a.

Fuel choice

See descriptions in Section 8.4

Applicable within the constraints associated with the availability of different types of fuel and/or an alternative use of the process fuel

b.

Boiler sorbent injection (in-furnace or in-bed)

Applicable to existing combustion plants within the constraints associated with duct configuration, space availability and chemical installation safety.

Wet FGD and seawater FGD are not applicable to combustion plants operated < 500 h/yr.

There may be technical and economic restrictions for applying wet FGD or seawater FGD to combustion plants of < 300 MWth, and for retrofitting combustion plants operated between 500 h/yr and 1 500 h/yr with wet FGD or seawater FGD

c.

Duct sorbent injection (DSI)

d.

Spray dry absorber (SDA)

e.

Wet scrubbing

See description in Section 8.4.

Wet scrubbing is used to remove HCl and HF when no wet FGD is used to reduce SOX emissions

f.

Wet flue-gas desulphurisation (wet FGD)

See descriptions in Section 8.4

g.

Seawater FGD

New and existing boilers

10–110

90–200

< 100

1–7

2–15⁽²⁾

< 1–3

< 1–6⁽³⁾

≥ 100

1–5

1–9⁽²⁾

< 1–2

< 1–3⁽³⁾

a.

Electrostatic precipitator (ESP)

See descriptions in Section 8.5

Generally applicable

b.

Bag filter

c.

Fuel choice

See description in Section 8.5.

Use of a combination of process fuels from the chemical industry and auxiliary fuels with a low averaged dust or ash content

Applicable within the constraints associated with the availability of different types of fuel and/or an alternative use of the process fuel

d.

Dry or semi-dry FGD system

See descriptions in Section 8.5.

The technique is mainly used for SOX, HCl and/or HF control

See applicability in BAT 57

e.

Wet flue-gas desulphurisation (wet FGD)

< 300

2–5

2–15

2–10

2–22⁽³⁾

≥ 300

2–5

2–10⁽⁴⁾

2–10

2–11⁽³⁾

a.

Activated carbon injection

See description in Section 8.5

Only applicable to combustion plants using fuels derived from chemical processes involving chlorinated substances.

For the applicability of SCR and rapid quenching see BAT 56 and BAT 57

b.

Rapid quenching using wet scrubbing/flue-gas condenser

See description of wet scrubbing/flue-gas codenser in Section 8.4

c.

Selective catalytic reduction (SCR)

See description in Section 8.3.

The SCR system is adapted and larger than an SCR system only used for NOX reduction

PCDD/F⁽¹⁾

ng I-TEQ/Nm³

< 0,012–0,036

TVOC

mg/Nm³

0,6–12