basic materials and example of ippc permit

Transcription

Eşleştirme Projesi TR 08 IB EN 03
IPPC – Entegre Kirlilik Önleme ve Kontrol
T.C. Çevre ve Şehircilik Bakanlığı
Integrated permitting for oil refineries: 3rd
training
BASIC MATERIALS AND EXAMPLE OF
IPPC PERMIT
DOCUMENT
Agenda
Structure of an Integrated Environmental Permit
Permit contents case study
Presentation EIA versus Integrated Environmental Permit
Coordination between the EIA and the Integrated Environmental Permit (IEP)
Example of IPPC permit from the UK
Vekaletler Caddesi No:1 06650 Kızılay ANKARA
http://www.csb.gov.tr/
Agenda
Integrated permits for oil refineries: training mission 3
Act. 4.2.d.3
17th– 20th of June 2013
MS Experts: Luis Suárez, Joan Ramon Cabello (Spain)
Objectives:
-
Explain the objective, materials and methodology of training.
-
Training and exercises.
Outputs of mission: Example of permit, training delivered, questionnaire completed by participants.
AGENDA
th
Monday 17 of June
-
09:30 – 12:45
o
Introduction to training materials and methodology of this training mission
o
Presentation of the draft of permit
-
12:45 – 14:00 Lunch break
-
14:00 – 17:00:
o
Discussion about coordination between EIA and IED procedures
th
Tuesday 18 of June
-
09:30 – 12:45
o
Discussion about air emission ELVs
-
-
14:00 – 17:00:
o
Discussion about other ELVs in the permit
th
Wednesday 19 of June
-
09:30 – 12:45
o
BATs and monitoring in the permit.
-
-
14:00 – 18:00:
o
Other aspects and conditions in the permit
o
Final conclusions
th
Thursday 20 of June
-
Morning:
o
08:00 – 10:00

Questions and answers.
INTEGRATED ENVIRONMENTAL PERMIT CONTENTS
1. General information
1.1. Legal background
1.1.1. Legislation applied to issue the permit
1.1.2. (Period of) validity of the permit
1.1.2.1. It will include exceptions
1.1.3. Other permits and licenses (prior to the IEP)
1.2. Competent Authorities involved
1.3. Provisions on the minimization of long-distance or transboundary pollution
2. Description of the installation
Name of the installation1
Owner of the installation
Operator of the installation2
Activity of Annex 1 of the by-law
Total number of workers
Location
2.6.1. Address
2.6.2. UTM coordinates (X and Y)
2.7. Characteristics of the installation
2.7.1. Register number of industrial establishments and NACE codes
2.7.2. Starting date of the activity and retrofitting (substantial changes)
2.7.3. Activity (principal and auxiliaries).
2.7.4. Products and by products
2.7.5. Summary of the main productive processes, including:
2.7.5.1. Flow chart
2.7.5.2. Consumptions: energy, fuels, water, raw materials (in the case of
waste management installations, the types and quantity of waste treated)
and auxiliary materials.
2.7.6. Nominal production / treatment capacity and size (number of places for
animals in the case of farms)
2.7.7. Operational time of the installation
2.7.8. Relevant environmental aspects
2.7.9. Other relevant information (ISO, EMAS...)
2.1.
2.2.
2.3.
2.4.
2.5.
2.6.
3. Environmental conditions
3.1. Atmosphere
3.1.1. Air quality
3.1.1.1. Immission Limit Values for the surroundings
1
Name and number assigned to this file (it should remain unchanged independently of changes
of owner or name).
2
In case the owner is different from the operator..
3.1.1.2. Monitoring and modelization requirements
3.1.2. Emissions
3.1.2.1. Channelled emissions
3.1.2.1.1. Characterization of the emission points: code of the point, height,
UTM coordinates, mass flow of the different pollutants
3.1.2.1.2. Requirements and technical conditions of the focus (including
operational hours)
3.1.2.1.3. Emission Limit Values (ELV), other equivalent parameters or
technical measures
3.1.2.1.3.1. Description BAT implementation.
3.1.2.1.4. Monitoring and control:
3.1.2.1.4.1. Normal operating conditions and measurements for not normal
operating conditions
3.1.2.1.4.2. Measurement methodology
3.1.2.1.4.3. Frequency
3.1.2.1.4.4. ELV assessment procedure
3.1.2.2. Non channelled emissions (fugitive emissions)
3.1.2.2.1. Description of the emission points
3.1.2.2.2. Emission Limit Values (ELV), other equivalent parameters or
technical measures.
3.1.2.2.2.1.Description BAT implementation.
3.1.2.2.3. Monitoring and control:
3.1.2.2.3.1. Measurement methodology
3.1.2.2.3.2. Frequency
3.1.2.2.3.3. ELV assessment procedure
3.2. Noise emissions
3.2.1.Characterization of the main sources
3.2.2.Emission Limit Values (ELV), other equivalent parameters or technical
measures.
3.2.2.1. Description BAT implementation.
3.2.3.Monitoring and control:
3.2.3.1. Measurement methodology
3.2.3.2. Frequency
3.2.3.3. ELV assessment procedure
3.2.4.Inspection
3.3. Waste water discharges
3.3.1.Description of the waste water flows (including process, sanitary and rain
waters)
3.3.2.Requirements and technical conditions of discharging points
3.3.3.Description of pollutants
3.3.4.Emission Limit Values (ELV), other equivalent parameters or technical
measures.
3.3.4.1. Description BAT implementation.
3.3.5.Monitoring and control:
3.3.5.1. Normal operating conditions and measurements for not normal
operating conditions
3.3.5.3. Frequency
3.3.5.4. ELV assessment procedure
3.4. Waste
3.4.1. Waste from production processes
3.4.1.1. Hazardous wastes
3.4.1.1.1.
Waste production
3.4.1.1.1.1.
Characterization of waste
3.4.1.1.1.2.
Plan for the minimization of waste
3.4.1.1.1.3.
Storage conditions
3.4.1.1.1.4.
Description BAT implementation
3.4.1.1.2. Waste management
3.4.1.1.2.1. Offsite transfer to authorised waste operators
3.4.1.1.2.2. In-site treatment of waste
3.4.1.1.2.2.1. Admission procedure for waste
3.4.1.1.2.2.2. Treatment operations
3.4.1.1.2.2.3. Technical requirement for disposal
3.4.1.2. Non-Hazardous wastes
3.4.1.2.1. Waste production
3.4.1.2.1.1. Characterization of waste
3.4.1.2.1.2. Description BAT implementation
3.4.1.3. Packaging and packaging waste
3.4.1.3.2. Plan for the minimization of waste
3.4.2. Other waste not related to production processes
3.4.2.1. Hazardous wastes
3.4.2.1.1.2. Plan for the minimization of waste
3.4.2.1.1.3. Storage conditions
3.4.2.1.1.3.1. Description BAT implementation.
3.4.2.1.2. Waste management
3.4.2.1.2.1. Offsite transfer to authorised waste operators.
3.4.2.1.2.1.1. Admission procedure for waste
3.4.2.1.2.1.2. Treatment operations
3.4.2.1.2.1.3. Technical requirements for disposal
3.4.2.2. Non-Hazardous wastes
3.5. Soil and groundwaters protection
3.5.1. Soil characterization and composition
3.5.2. Preventive actions regarding lower environmental impact
3.5.2.1. Safety measures for storages.
3.5.2.2. Systems of drainage or collection of potentially polluted waters.
3.5.3. Monitoring and control of the groundwaters
3.5.3.2. Frequency
3.6. Inspections
3.6.1. Generic requirements to be fulfilled by the operator to facilitate inspections
4. Technical annexes
4.1. Unusual situations (not normal operating conditions) which may affect the
environment
4.1.1. Exceedance of ELV established in the permit
4.1.2. Shut-down and start-up conditions
4.1.3. Accidents and incidents related to leakages, malfunctions and momentary
stoppages
4.1.4. Definitive cessation and dismantling
4.2. Emergency plans
4.3. Environmental information to provide to the Competent Authority
4.3.1. Reporting on monitoring and control actions3 and assessment of compliance
with Emission Limit Values4.
4.3.2. Reporting related to exceedance of ELV associated to BAT.5
4.3.3. Assessment of efficiency of measures adopted after ELV’ exceedance
episodes.
4.4. Mainteinance and calibration plan
4.4.1. Production and auxiliary equipments
4.4.2. Automatic measurement system
5. Other annexes
5.1. Final Report on EIA
5.2. SEVESO report (classification of the installation according to applicable
legislation on control of major-accident hazards involving dangerous substances)
3
actions performed by the operator
for each environmental aspect it must be specified what kind of information will be requested to
the operator, and the operator must justify the methodology used to obtain the data and verify the
compliance with the permit conditions.
5
The operator has the obligation to report, where the emission limit values used exceed the
emission limit values associated with the best available techniques (BATs), a summary of the
results of emission monitoring which allows a comparison with the emission levels associated
with the best available techniques.
4
www.csb.gov.tr/projeler/ippc
PERMIT CONTENTS CASE STUDY
1. GENERAL INFORMATION
In the structure of contents proposed for the integrated environmental permit there is a first
section named “general information” where some considerations about legislation must be
done. In this section we consider that should be included the legal references used in all the
technical documents related to the permit application, the period of validity of the permit and
a statement in case that some other permits or licenses must be obtained.
2. DESCRIPTION OF THE INSTALLATION
2.1 Name, owner and operator of the installation

INVENTED OIL COMPANY, Ltd

TWINNING EXAMPLE

VAT NUMBER: XXX-XX-X-XX

ADDRESS: ….. …. …. TURKEY

TELEPHONE: 111-111-111

FAX: 222-222-222

E-MAIL: IOILCOMPANY@PPP.COM

The owner of the installation is the INVENTED OIL COMPANY, Ltd, and the legal
representative is Mr. ……………. The person in charge of the environmental issues is
Miss. …………………………
COMPANY
Trade name xxxxx
Head office xxxx
ZIP code
xxxx
Province xxxx
INSTALLATION
Name xxxx
Adress xxxxxx
City xxxx
City xxx
VAT xxxx
ZIP code xxxx
Province xxxxx
1/21
2.2 Activity of Annex 1 of the by-law, total number of workers
CHARACTERIZATION OF WORKING REGIME
Permanent 500
Temporal
1000
Working hours
Hours/year 8760
Date of the start of the activity of the Forecast at 2014
facilities
Coordinates UTM
X: 351000
Y: 4550000
UTM zone: 36
0
Geographical coordinates
Latitude: x xx’ xx’’
Length: x0 xx’ xx’’
Extension of the Facility [m2] 800.000
Neighboring settlement areas: - XXXX town
- YYY village
Nearby infrastructure*
Environmental elements affected*- Nature reserve of XXX at 60 km
- Endemic flora reserved zone at 130 km
Number of staff
CATEGORY OF ACTIVITIES AND FACILITIES
Main category of activity /Facility
1.2
Mineral and Oil refineries
NACE (National Classification of Economic Activities) code: XXX-XXX-XXX
Investments in the last 4 years targeted to environmental improvements(only for existing
installations):
- Sulphur recovering systems: 250 MM€
- Double capacity in ECOVs WWTP: 60 MM€
2/21
2.3 Location, and characteristics of the installation
A general scheme of the installations is:
Refinery
Underground pipeline
Storage facility
Aerial pipeline
MARPOL facility
Jetty
This permit is only granted for the refinery installation.
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As was shown in the application documentation and the urban compatibility permit, the
refinery is located at an industrial zone considered for “large industrial sites”
The technical characteristics of the refinery are:
The data about the whole refinery could be explained with the next chart:
Total emissions 2.000.000 Nm3/h
CO2 3.000.000 t/y
SO2 25.000 t/y
NOx 5.000 t/y
PM 600 t/y
Sulfur 40.000 t
COVs 900 t/y
LPG 175.000 t
Propellants 30.000 t
Electricity 400.000.000 kWh
Gasoline 1.400.00 t
Water 7.500.000 m3
Kerosene 750.000 t
Crude oil 8.000.000 t
Gas-oils 3.700.000 t
Nafta 700.000 t
Fuel oil 1.500.000 t
Alcohols 60.000 t
Refinery
Ethylene 700.000 t
Butens 140.000 t
Propylene 570.000 t
Gas Natural 300.000 t
C4 Fraction 200.000 t
Hidrogen 35.000 t
Aromatics 230.000 t
Heavy FO 650.000 t
Total waste water
2.700.000 m3/y
Energy 220 GWh
Steam 1.400.000 t
Total non dangerous
waste: 6.000 t/y
Total dangerous waste:
900 t/y
These data will be taken under consideration in order to the substantial or non-substantial
character of possible future modifications of the refinery.
The present permit is granted for the next facilities:
o Desalting unit
o Primary distillation units
o Wastewater plant treatment
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Desalting unit description
a) Purpose and principle: Crude oil and heavy residues can contain varying quantities of
inorganic compounds such as water soluble salts, sand, silt, rust and other solids, together
characterised as bottoms sediment. These impurities, especially salts, can lead to fouling and
corrosion of heat exchangers (crude preheaters) and especially the crude distillation unit
overhead system. In addition, salts are detrimental to the activity of many of the catalysts used
in the downstream conversion processes and sodium salts stimulate coke formation (e.g. in
furnaces). The principle of desalting is to wash the crude oil or heavy residues with water at
high temperature and pressure to dissolve, separate and remove the salts and solids.
b) Feed and products streams: Crude oil and/or heavy residues (oily feedstock) and reused and
fresh water are the feedstreams to the desalter and washed crude oil and contaminated water
are the outputs of the desalting processes. The water phase from the overhead crude
distillation unit of the overhead and other used water streams are normally fed to the desalter
as washwater.
c) Process description: After preheating to 115 – 150 °C, the oily feedstock is mixed with water
(fresh and preused water) in order to dissolve and wash out the salts. Intimate mixing takes
place between the oil and the wash water together in a globe valve mixer, a static mixer or a
combination of both. The water must then be separated from the oil feedstock in a separating
vessel by adding demulsifier chemicals to assist in breaking up the emulsion and/or, more
commonly, by applying a high potential electric field across the settling vessel to coalesce the
polar salt water droplets. Either AC or DC fields may be used and potentials from 15 to 35 kV
are used to promote coalescence.
The separation efficiency depends on pH, density and viscosity of the crude oil, as well as the
volume of wash water used per volume of crude. Many refineries have more than one desalter
and multiple-stage desalters also exist.
The washwater containing dissolved hydrocarbons, free oil, dissolved salts and suspended
solids is further treated in an effluent treatment plant.
Where bottoms sediments are critical in downstream process units, desalters are equipped
with a bottom flushing system to remove settled solids.
Primary distillation units description
This section includes atmospheric and vacuum distillation. These two primary distillations are
preceded by crude oil desalting and they are the first and fundamental separation processes in
a refinery.
a) Purpose and principle: In Atmospheric Crude Oil Distillation Unit (CDU), crude oil is heated
to elevated temperatures and then generally subjected to distillation under atmospheric
pressure (or slightly higher) separating the various fractions according to their boiling range.
Heavier fractions from the CDU bottom of the, which do not vaporise in this column, can be
further separated later by vacuum distillation, which is simply the distillation of petroleum
fractions at a very low pressure to increase volatilisation and separation whilst avoiding
5/21
thermal cracking. The high vacuum unit (HVU) is normally the first processing step in upgrading
atmospheric residue followed by downstream refining units. HVU produces feedstocks for
cracking units, coking, bitumen and base oil units. The contaminants from the crude oil stay
predominantly in the vacuum residue.
b) Feed and products streams: The crude oil feed to the crude distillation unit is supplied from
the crude oil storage tanks after desalting. Normally all crude oil entering a refinery passes
through a crude distillation unit. In addition to that, it is common practice that off-specification
product streams are reprocessed in the CDU.
The products from the crude distillation unit, ranging from the lightest to the heaviest cut are:
naphtha and light components (boiling <180 °C/C1-C12 lights, naphtha and gasoline)
kerosene (boiling range 180 – 240°C – C8-C17)
light gasoil (boiling range approximately 240 - 300 °C/C8-C25)
heavy gasoil (boiling range approximately 300 – 360 °C/C20 - C25)
atmospheric residue (boiling >360 °C/>C22).
The overhead of this column is the light fraction, non-condensable refinery fuel gas (mainly
methane and ethane). Typically this gas also contains hydrogen sulphide and ammonia gases.
The mixture of these gases is known as ‘sour gas’ or ‘acid gas’. A certain amount of it passes
through the condenser to a hot well, and is then discharged to the refinery sour fuel system or
vented to a process heater, flare or other control device to destroy hydrogen sulphide.
The main feed stream to the HVU is the bottom stream of the crude oil distillation unit,
referred to as atmospheric or long residue. In addition the bleed stream from the hydrocracker
unit (if applicable) is normally sent to the HVU for further processing. The products from the
HVU are light vacuum gasoil, heavy vacuum gasoil and vacuum residue. Light vacuum gasoil is
normally routed to the gasoil hydrotreater(s), heavy gasoil is normally routed to a fluid cat
cracker and/or hydrocracker unit. The vacuum residue can have many destinations such as
visbreaking, flexicoking or delayed coking, residue hydroprocessing, residue gasification,
bitumen blowing or it may go to the heavy fuel oil pool.
c) Process description of Atmospheric distillation: Distillation involves the heating, vaporisation,
fractionation, condensation, and cooling of feedstocks. The desalted crude oil is heated to
about 300 – 400 ºC and fed to a vertical distillation column at atmospheric pressure where
most of the feed is vaporised and separated into its various fractions by condensing on 30 to
50 fractionation trays, each corresponding to a different condensation temperature. The
lighter fractions condense and are collected towards the top of the column. The overhead
hydrocarbon vapours are condensed and accumulated in the overhead reflux drum of the
main fractionator. In this drum sour water, light fractions (about 0.5 % on crude charge) and
stripping steam (1.5 % on crude) are separated from the hydrocarbon liquid. The overhead
hydrocarbon liquid, so called the naphtha minus stream, is commonly fed directly to the
downstream naphtha treater.
6/21
Within each atmospheric distillation tower, a number of side-streams of low-boiling point
components are removed from different trays in the tower. These low-boiling point mixtures
are in equilibrium with heavier components which must be removed. The side-streams are
each sent to a different small stripping tower containing four to ten trays with steam injection
under the bottom tray. The steam strips the light-end components from the heavier
components and both the steam and light-ends are fed back to the atmospheric distillation
tower above the corresponding side-stream draw tray. Most of these fractions generated in
the atmospheric distillation column can be sold as finished products after a hydrotreatment, or
blended with products from downstream processes.
The operating conditions of the tower are based on the properties of the crude oil and the
desired product yields and quality. Every refinery has a crude distillation unit designed for a
selected crude (mix).
Process description
The main process to obtain all the different products from crude oil is the crude oil distillation.
The refinery used for this case study has two units of crude oil distillation. The distillation unit
has a capacity of 8.500.000 t of crude oil a year. In these units, the crude oil is separated into
different fractions depending on their boiling point: LPG, naphtha, kerosene, diesel, etc.
The following units are subject to this permit:
-
Feeding system with pumps that transport the crude oil from storage tanks to the
units, giving the proper pressure to be able to introduce them to the process.
-
Heat exchangers, which heat the crude oil before and after the desalting units using
the hot flows from the same unit.
-
Desalting unit, where the salt within the crude oil is eliminated through water
injection.
-
Loading furnace, to increase the temperature of crude oil until the necessary
temperature for fractioning.
-
Distillation column, where all the crude oil components are separated into fractions,
from lightest ones, extracted through the head of the column, until the heaviest ones,
extracted through the bottom of the column. There are also several lateral extractions
for intermediate products.
-
Stripping columns, where the lightest products of the three intermediated fractions
are removed. The objective is to remove light components from kerosene, diesel and
atmospheric gas oil, in order to reduce their ignition point.
The fractions obtained in the crude distillation are:
- LPG
- Non stabilized naphtha
- Kerosene
- Diesel
- Atmospheric GO
7/21
-
Atmospheric waste, that is the bottom fraction that is not possible to distillate under
atmospheric conditions.
Natural resources, raw and auxiliary materials and products:
Raw material
Crude oil
Consumption
8.500.000 t/y
Storage
570.000 t
Catalyst
90 t/y
380 t
Anthracite and silica 30 t/y
sand
Rasching/pall rings
7 m3/y
41 t
Ceramic balls
15 t
19 m3
23 t/y
Steam and condensate 8.000 t/y
treatment products
Additives
13.000 t/y
5t
Oils and greases
4.500 t/y
58 t
Other
90.000 t/y
150 t
14 t
Storage facilities
7 atmospheric cylindrical
tanks with floating roof
Several tanks and storage
facilities
facilities
facilities
facilities
facilities
facilities
facilities
facilities
And the obtained products (most of theme after other processes but originated in this unit)
are:
Product
LPG
Kerosene
Fuel oil
Gas oil
Gasoline
Amount produced
175.000 t/y
745.000 t/y
1.500.000 t/y
3.700.000 t/y
1.400.000 t/y
Storage
16.000 t
60.000 t
325.000 t
400.000 t
120.000 t
Annual consumption: crude oil
Year
2012
2011
2010
2009
Annual
(MT)
8.500.000
8.450.000
8.510.000
8.100.000
amount
% sulphur (average)
1,3%
1,5%
1,5%
1,6%
8/21
Storage facilities
Pressured aerial spheres
Atmospheric aerial tanks
Annual consumption: water and electricity
Year
2012
2011
2010
2009
Water
Annual
(m3)
7.500.000
7.450.000
7.510.000
7.100.000
amount
Electricity (selfconsumption)
(MWh)
450.000
440.000
441.000
438.000
Electricity generated: (cogeneration units)
Year
2012
2011
2010
2009
Electricity generated( MWhb)
445.000
435.000
436.000
433.000
Significant changes in any parameter may lead to its consideration as a “substantial
modification”.
9/21
3. ENVIRONMENTAL CONDITIONS
3.1 AIR
3.1.1 Channeled air emissions
The total polluted air emissions in the unit will be channeled through the same general stack
located at:
UTM X: 351.000
UTM Y: 4.550.000
As a result of the dispersion model study, the height of the stack will be, at least, 113.8 m and
the inner diameter will be 7.76 m.
This height guarantees, according with the results of the dispersion model analyzed (during
the EIA procedure as well as this IED/IPPC procedure) that the air quality levels, in the
surroundings or the refinery, will fulfil the standards in that scope.
The stack will be equipped with four points of measuring and a platform. The measurement
points are located at 3 times the diameter length from the outside and 6 times the diameter
length from the last perturbation.
The installation shall fulfil the next emission limit values thar are established in dry basis and
normal conditions of pressure and temperature. (P=101,3 kPa i T=273 K). All the values will be
corrected to a 3% O2 contents for combustion process with liquid or gaseous fuel.
Stack: 1
Pollutant
Description: distillation unit
Emission limit value
PST
25 mg/Nm3
CO
100 mg/Nm3
Value origin
Table 4.3, BAT Turkish
Guide for oil refineries
5 – 25 mg/Nm3
for new units > 50 MWth
<100
mg/Nm3
daily
average.
10/21
Stack: 1
Description: distillation unit
Pollutant
Emission limit value
Value origin
30 – 150 mg/Nm3
35 – 350 mg/Nm3
NOx, com a NO2
150 mg/Nm3
SO2
350 mg/Nm3 (*)
H2S
5 mg/Nm3 (**)
TA luft 2002
COVs
50 mg/Nm3 (***)
TA luft 2002
Metals
Not determined in European
BREFs
(*) For the EU refining sector the Directive 2010/75/EU on industrial emissions (Annex V, Part
7) sets the emission limit values for multi-fuel firing combustion plants. According to this
Annex V, 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, have to comply with the following
average emission limit values for SO2:
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: 1000
mg/Nm3;
b) For other combustion plants: 600 mg/Nm3.
However, this Directive also states that, on the basis of the best available techniques, the
European Commission shall review the need to establish EU-wide emission limit values and to
amend these emission limit values. It would be expectable that this review would lead to the
establishment of similar values to those in the BREF document for oil and gas refining.
In addition to this, the national legislation in Turkey establishes, through the 27277 By-Law on
Control of Air Pollution caused by Industry, the emission limit values for combustion facilities
using liquid fuels. As it has been explained in the BAT Guide for oil refineries prepared within
the context of the IPPC Twinning Project, the refining industry in Turkey may have certain units
that have not been designed according to the new European legislation and which still have an
operation lifetime that can last for many years, and it could be the case of the combustion
units that operate only with liquid fuels. For these units, a transition period should be
regulated by the competent authorities taking into account the emission limit values set in
Annex 5 paragraph 4.4 of the above mentioned 27277 By-Law.
11/21
(**) In the case of the Spanish refinery of Puertollano there is an emission limit value of 5
mg/Nm3 for H2S, however there are no BAT-AELs associated to this pollutant. In our opinion, it
could be acceptable that the competent authorities decide not to set emission levels of H2S in
this stack, because under normal conditions the main sulphur compound will be SO2.
(***) We propose an emission limit value of 50 mg/Nm3 for COVs, however there are no BATAELs associated to this pollutant. In our opinion, it could be acceptable that the competent
authorities decide not to set emission levels of COVs in this stack, because under normal
conditions the possible organic compounds will be in their oxidized form.
Bubble limits (Puertollano refinery –example-)1
For the evaluation of global emissions from the refinery (emissions bubble), it shall be
established a limit in terms of the annual average concentration, which will cover the
combustion units of the refinery, conventional and non-conventional facilities, including
cogeneration units.
Bubble limits:
PARAMETER
ELV
Unit
SO2
PST
Nox
1000
50
450
mg/Nm3
mg/Nm3
mg/Nm3
% O2
Dry basis
3%
3%
3%
Bubble mass flow:
The applicable emission values in terms of mass flow from bubble units, expressed in tons,
shall be:
PARAMETER
SO2
PST
NOx
ELV
15.000
600
5000
Unit
Tm/ year
Tm/ year
Tm/ year
Measurement methods
The measurement methods specified below are considered as the most appropriate at the
moment to issue this environmental permit. If in the future, any new more suitable rules or
UNE EN norms are published which are applicable to this type of installation, these methods
shall be adopted for the implementation of relevant controls.
The measurement methods for general parameters are:
1
Bubble limits, as concentrations or flow mass is an interesting topic to discuss during
the training
12/21
Measurement method
Parameter
Flow & Speed
Humidity
UNE 77225:2000
UNE-EN 14790
Continuous measurement
Access and working platforms at sampling points in the stack shall fulfill the provisions of
Turkish by-law relative to the minimum safety and health conditions in the workplace.
All continuous measuring systems must be calibrated by an accredited environmental control
body or consultancy firm.
The calibration of the analyzers of source 1 will be made according to the Standard EN 14181
and, therefore, as established in the rule:
An annual follow-up test must be made (with a prior functionality test).
A calibration with a reference method must be made carried out (NGC2) every 4 years
(prior to the functionality test).
Procedures for “zero deviations” and "span" must be done (NGC3) continuously by the
responsible for the installation.
Prior to implementation of the facility it must be presented a project with the technical
characteristics of the equipment, the location and the time of implementation that must be
approved by the competent authority.
Continuous measurements of pollutant sources will be considered as fulfilling the ELV if:
None of the monthly averages exceed the ELV over the period of a year and
97% of the averages of 48 hours for pollutants SO2 and TSP do not exceed 110% of the
emission limits and
95% of the averages of 48 hours for NOx do not exceed 110% of the emission limits.
The data collected, which must be stored for a minimum period of five years, should be
available for any inspection carried out by the competent authority.
All facilities monitored continuously (both emission sources and flares), must have the
necessary equipment for sending the information related to parameters and pollutant
emission controlled continuously to the competent authorities.
The owner, for those equipment installed in continuous (pollutant analyzers and measuring of
different parameters) in which there is no connection to the competent authority, must submit
monthly the emission data according to the format established in the competent authority’s
template for communications.
In the event that any anomaly occurs in the operation of continuous emissions monitoring
systems or emissions are detected which are higher than some legal limit emission levels for
two or more consecutive half-hours, local authorities must be informed immediately.
13/21
In case of a failure of the measurement system which prevents continuous emission signals to
be recorded continuously for a period exceeding 48 hours, this will be communicated to the
local authorities who will define an alternative monitoring plan, if appropriate, in accordance
with current legislation and the environmental permit.
Emissions through flares
The units authorized and the rest of the refinery will use the same flare as a safety system to
treat discharges from any unit in case of emergency shutdown, electrical failure o any other
anomalous situation.
To this system will be also sent other gases from purges, safety valves, vents or any other
discontinuous combustible flows, to avoid sending them directly to the atmosphere without
being treated.
To estimate the work time of the flare it could be assumed that it is running 24h/day all the
year, because, although there is no any continuous flow sent to the flare, there are a lot of
discontinuous flows sent to it so it could be assumed that it will be running almost in a
continuous way.
The flare will be located at:
UTM X: 350.000
UTM Y: 4.500.000
In order to avoid the impacts of the noise, the height of the flare will be at least 100 m and the
inner diameter 1,5 m.
Immediately before the flare, there will be located a recovery system composed, basically, by a
compressor with the capacity of liquefy 2t/h of gasses that will be reused in the process as
fuel-gas to reduce air emissions and energy consumption.
The flare will work as a security device to release the pressure of the units within the
installation, both in normal and emergency conditions. If the owner cannot meet this
condition, he shall submit, within six months, a project to implement a system to minimize
these waste gas streams.
The flare will be equipped with flow meters (with variable interval range) recording
continuously the volumes of different streams sent to the flare system.
For the flare, the owner will have a specific log book where all incidents outside the normal
operation of the activity causing the delivery of gas to the flare will be registered. The book
must be numbered, and approved by the competent authority.
In the case of black smoke and flames visible in the flare, the owner must notify, by fax or
email to the competent authorities, the forecast duration and effects of the incident. This
notification will be made before the incident or as soon as possible.
14/21
3.1.2 Diffuse air emissions
To avoid fugitive or diffuse emissions of substances (excluding odour, noise and vibration) the
operator shall maintain a LDAR (Leak Detection and Repair) programme for testing potential
sources of fugitive emissions of VOCs from different units at the installation, as described in its
application. (See Chapter 5 of the Turkish Guide)
The establishment of LDAR systems are systems considered as a BAT for oil refining systems
with a prevision of a 40-60% of reduction in diffuse emissions of VOCs.
3.1.3 Noise emissions to the surroundings of the installation:
The operator shall maintain a noise management plan with, at least, the next scope:
-
Absorbent materials of special mineral wool installed at the exit of valves and
pipelines.
-
Noise dampers in some electrical motors.
-
Silencers in some critical vents.
-
Sound screens and baffles to surround the ventilator of crude oil pumps.
The operator shall review the plan annually and record at least once a year or as soon as
practicable after a complaint (whichever comes earlier), whether changes to the plan should
be made and make any appropriate changes to the plan identified after its review.2
2
If the operator has not an exception regarding this issue
15/21
3.2 Wastewater discharges:
The description of the system of wastewater treatment and its different lines is as follows:
WATER LINE 1: that connects the next water streams:
- Sour and ammonia waters, from condensate distillation, condensation, coking and
cracking units.
- Oily water of cracking, refineries, lubricants and conversion units.
- Stripping towers.
These streams are combined in a single flow, which passes through the API3 separators
to remove completely the oils. These separators consist of 2 units of 550 m3 each, with
2 channels and collection and pumping system.
There are two possible destinations of water line 1:
-
Separation of oils by dissolved air flotation (DAF4), composed by 6 equal cells
with a unitary volume of 160 m3.
2 ponds with 12000 and 8000 m3 of capacity to retain and dose the amount of
rain water or wastewater sent for further treating, regulating the flow.
o
-
Union to waterline 2, before the final treatment:
WATERLINE 2 :
 Wastewater from offices, laboratories access: sent directly to the final
treatment (WATERLINE 3).
 Cleaning purges from cooling towers: separation of oils.
o
o
Union of different streams in WATERLINE 2, with 2 possible destinations:
Gravimetric decanter.
2 ponds with 5000 and 4000 m3 of capacity to retain and
dose the amount of rain water or wastewater sent for
further treating which is connected to gravimetric decanter.
Separation of oils (DAF)
3
API oil-water separator: device designed to separate bulk amounts of oil and suspended
solids. The name is derived from the fact that such separators are designed according to
standards published by the American Petroleum Institute.
4
Dissolved Air Flotation (DAF) process which cleans wastewaters by the removal of suspended
matter such as oil or solids.
16/21
o
-
Union to waterline 1, before the final treatment:
WATER LINE 3 (FINAL TREATMENT):
o
o
o
o
Union of all previous flows in pools of pre-aeration with diffusers that
receive air through blowers. A chemical oxidation of dissolved organic
matter takes place at this stage.
Biological treatment: hydraulic regime in flow on piston with 8 parallel
channels and oxygenation with diffusers that receive air through blowers.
4 conical bottom decanters of 2,100 m3 of capacity with sludge
recirculation.
Pools to oxygenate the effluent before discharge:
- Oxygenation pond of 800 m3 by turbines.
- Pond of tertiary treatment of 10,000 m3 with perimeter of banks with
reeds and canes in order to favour photosynthesis. Waters must be
recirculated to the head of the refinery.
- Final pond before the final discharge through a concrete channel.
- Before that channel there will be two samplers to scan and monitor
the concentrations of TOC, NH3 and F-.
SLUDGES LINE:
From WATERLINE N1:
- Sludges generated in API: Wastes treated by an external authorised company.
- Sludges generated in cells: they must be recovered in the Coke Unit, like cooling
chambers waters. The excess water will be sent to centrifugation and dryed for its
subsequent treatment by an external authorised company.
From WATERLINE N2:
- Sludges generated in the primary decanter: they will be mix with sludges generated in
cells following the same destination.
Sludges generated in cells: they must be recovered in the Coke Unit, like cooling
chambers waters. The excess water will be sent to centrifugation and dryed for its
subsequent treatment by an external authorised company.
From FINAL TREATMENT:
- Purge of biological sludges must be recovered in the Coke Unit, like cooling chambers
waters. The excess water will be sent to centrifugation and dryed for its subsequent
treatment by an external authorised company.
17/21
Limits:
Parameter
Unit
Hydrocarbon Oil
index (HOI)
mg/l
LIMIT
Proposal
(yearly
average)
2.5
BAT-AEL
(yearly average)
(BAT Turkish
Guide)
mg/l
25
mg/l
125
Total nitrogen (3)
(expressed as N)
Lead, expressed as Pb
Cadmium, expressed
as Cd
Nickel, expressed as
Ni
Mercury expressed as
Hg
Vanadium
Phenol Index
mg/l
25
1 – 25(6)
mg/l
mg/l
0.030
0.008
0.005 – 0.030
mg/l
0.1
30 – 125
Daily
40
2
0.001
mg/l
mg/l
Quarterly
0.000 1 – 0.001
No BAT-AEL
mg/l
Benzene:
0.050
Benzene: 0.001 –
0.050
No AEL for T,E ,X
reporting only
(1)
Quarterly
Quarterly
0.005 – 0.100
mg/l
Weekly
Daily
0.002 – 0.008
No BAT-AEL
Benzene, toluene
Ethyl benzene,
Xylene (BTEX )
Daily
5– 25
No BAT-AEL
Monitoring (1)
frequency
Daily with EN
9377-2
analytical
method (4)
0.1 – 2.5
Total suspended
solids (TSS)
Chemical oxygen
demand (COD)(2)
BOD5
mg/l
LIMIT
(Puertollano
Refinery)
Quarterly
2
1.5
B: 0.05
E: 0.03
T: 0.05
X: 0.03
Quarterly
Monthly with
EN 14402
analytical
method
Flow
proportional
sample(1)/mon
thly
Refers to a flow-proportional composite sample taken over a period of 24 hours. Timeproportial sampling can be used provided sufficient flow stability is demonstrated
(2)
Where on-site correlation is available, COD may be replaced by TOC. The correlation
between COD and TOC should be elaborated case by case.
(3)
Where Total-Nitrogen = TKN + Nitrates + Nitrites
(4)
Moving from the current method to EN 9377-2 may require an adaptation period
(5)
Not all parameters and sampling frequencies are applicable to effluent from gas refining
sites
(6)
When nitrification/denitrification is used, levels below 15 mg/l can be achieved
18/21
3.3 Waste management
The operator shall implement the waste management plan, to ensure, in this priority order,
that waste is prepared for reuse, recycling, recovery or disposal (BAT).
This waste management plan must include the following techniques, that shall be applied in
the installation and which result in minimisation of wastes sent for disposal or external
treatment:
-
-
Correct conditioning of a catalyst extends the catalyst’s life
Process optimisation leads to less off-specification product and hence less recycling
Recycling caustic soda sufficiently to ensure it is completely spent.
The water treatment chemicals must be added in a controlled manner to reduce
excess sludge formation or scale build up.
Use of polyelectrolyte chemicals rather than inorganic flocculants such as ferric
chloride which generate excess sludge volumes.
Segregation of different wastes.
Sludge treatment by dewatering and drying with the purpose of reducing the volume
and the residual hydrocarbon content in order to save subsequent processing or
disposal costs. (BAT)
Oily sludge must be processed in units (coking) as part of the feed due to their oil
content. (BAT)
19/21
The wastes finally generated shall be below the folowing annual productions:
Waste
Hydrocarbons
Oily sludge
Caustic soda
Sludge from water
boilers
CaCO3
Ashes and dust of boilers
Process where it is generated
Maintenance
Cleaning and maintenance
Fuels cleaning
Boiler water treatment
Boiler water treatment
Cleaning of boilers and
furnaces
Blasting sands
Metallic surface treatments
Mineral oil
Lubrication
Containers and packaging All kind of packaging with
rests of dangerous materials
Gasoil filters
Filtration
Laboratory products
Laboratory analysis
Lead batteries
Batteries, cells, and others
with lead
Alumina waste
Catalyst change
Wasted catalyst
Catalyst change
Refractory material
Refractory maintenance
Dirty grit
Maintenance
Isolation material
Isolation maintenance
Dried sludge from WWTP Waste water treatment plant
Ion exchange resins
Water treatment
Paper and cardboard
General waste
Fluorescent tubes
General waste
Domestic batteries
General waste
Wood
Packaging
Plastic
Packaging and general waste
Metal scrap
Maintenance operations
General waste
General waste
Waste code
050106
050111
050113
050199
060405
100104
120117
130205
150110
150202
160803
160807
161106
170503
170504
170601
190813
190905
200101
200121
200138
200139
200140
200301
050106
050111
Production 5
25 t
100 t
35 t
225 t
2900 t
25 t
350 t
150 t
20 t
5t
0,2 t
1.5 t
35 t
94 t
90 t
30 t
50 t
380 t
8t
6t
4t
0,4 t
40 t
7t
500 t
1200 t
(The permit must include the rest of conditions related to handling and intermediate storages,
documentary control and rest of aspects included in the Turkish legislation)
5
In Spain, the waste production is limited in terms of rates of production and not in
terms of total amounts (to discuss during the training)
20/21
3.4 Soil and groundwater protection:
According to the monitoring plan carried out in the installation, there will be a prevention
program covering at least the following issues:
-
Maintenance of existing storage tanks, with the objective of failure detection and
correction, mainly at bottom of tanks before a hypothetical accidental release.
-
Underground pipelines maintenance to avoid corrosion. Hydraulic test will be
practiced to check if there is any leak.
-
Periodical monitoring using a network with, at least, 41 piezometers.
-
Within a period of two years, all underground pipelines shall be under cathodic
protection to avoid corrosion. 6
6
Example of adaptation measure to be discussed during the training
21/21
03/06/2013
Twinning Project TR 08 IB EN 03
Oil Refineries Training
Mission 3
Cesar Seoanez – Resident Twinning Adviser
Luis Suárez – Expert
Joan Ramon Cabello – Expert
EIA vs. IED
 Main possible situations where dialogue is
needed
 The Final Report on EIA evaluates unnecessarily
aspects typical of the IED/IPPC permit
 Sometimes it is better to issue a negative EIA
decision because of aspects that in principle must be
evaluated within the IPPC/IED permit procedure
Twinning project - TR/2008/IB/EN/03
EIA vs. IED
1
03/06/2013
EIA vs. IED
 Thus a coordination of the competent authorities
involved in EIA and IEP procedures is essential.
 A meeting between both authorities (EIA and IEP)
should be placed in order to avoid these problems
mentioned.
EIA vs. IED
1.- PRELIMINARY SITUATION.
For a new installation (as in our case under study):
These studies are very important in order to
establish the admissible impacts of the facilities. In
those cases, a careful analysis is needed and it is
highly recommendable a coordinated work between
the EIA and Permit Competent Authorities. This part of
the report should be analyzed by both authorities
during the suggested meeting.
EIA vs. IED
3.- OPERATION CONDITIONS
 It is important that the EIA decision does not
include operation conditions neither ELVs,
avoiding to invade the scope of the IEP. In this
sense, the EIA decision must be such that it will
support the “fulfillment of the conditions
that shall be imposed in the IEP”.
2
03/06/2013
EIA vs. IED
The goal of the EIA procedure consists in
evaluating the feasibility of the facility. Therefore,
its ELVs must be a “minimum” protection
requirement that, afterwards, the IPPC/IED permit
must be able to make stricter in order to be
compliant with the compulsory BAT Associated
Emission Levels.
EIA vs. IED
 It is necessary to remind that those BAT AELs
are based, not only on the basis of environment
protection, but also to guarantee a common level
playing field among different facilities of a given
sector within the countries affected by the IED.
EIA vs. IED
4. PLANNING OF THE MONITORING OPERATIONS
AND INSPECTIONS.
The Permit Competent Authority, in its global
assessment, will include all the monitoring
requirements, avoiding redundant demands,
ensuring an efficient global moniring and, during
the planned and suggested meeting with the EIA
authority, the possible disagreements should be
considerably reduced.
3
03/06/2013
EIA vs. IED
FINAL DECISION
The final decision, if some disagreement persists, should
be under the responsibility of a high level manager above
both groups of experts (EIA & IEP).
4
Coordination between the
Environmental Permit (IEP)
EIA
and
the
Integrated
SITUATIONS FACED IN PRACTICE:
During the permitting process, particularly in the integrated assessment phase of the whole project,
we can meet two possible situations that require a communication and coordination between EIA
and IEP experts:
-
The draft EIA Decision evaluates unnecessarily aspects typical of the IEP (for instance
emission limit values), limiting the capacity of imposing BAT Associated Emission Levels (BAT
AELs), monitoring and operation conditions, ELVs, etc, or even imposing certain dimensions
to the stacks, based for instance in the results of the dispersion model (evaluated in EIA
procedure).
-
For some cases where the permitting authority checks that an IEP cannot be issued for a
certain project proposal, it is better to issue a negative EIA Decision because of aspects that
in principle must be evaluated within the IEP procedure, in order to finish in a faster way the
procedure (for example, the EIA may not evaluate a priori a waste water discharge because it
considers that this aspect must be assessed by the IEP experts, and the IEP experts find the
discharge inadmissible, then it may be advisable to issue a EIA negative decision based on
that fact).
Considering the above mentioned interactions between EIA and IEP assessment, the
recommendation consists in making a case by case assessment always having a coordination of the
competent authorities involved in EIA and IED/IPPC procedures.
EIA ROLE WITHIN THE IEP PROCEDURE ACCORDING TO THE DRAFT BY-LAW
ON IEP:
If the installation which applies to obtain the integrated environmental permit (IEP) falls under the
scope of the By-Law 26939, published in the Official Gazette on the 07/07/2008, on Environmental
Impact Assessment (EIA), it will have to include in the permit application file the EIA report
mentioned in the article 11 of that By-Law (see figure below).
This means that the EIA procedure starts earlier, and the IEP application cannot be sent until the EIA
report mentioned in the article 11 of By-Law 26939 is available to be included. For those installations
that according to the By-Law 26939 do not require an EIA, or have a certificate of “No EIA required”,
no EIA report is required. For the second case (installation with certificate of “No EIA required”), the
operator will have to provide the certificate of “No EIA required”.
During the assessment of the permit application the IEP Competent Authority will work together with
the EIA Competent Authority to guarantee the compatibility of the contents of the EIA and the IEP
(red circles in the figure).
The IEP cannot be issued before the EIA final decision. If the EIA final decision is negative, the IEP
procedure stops and the IEP cannot be issued.
Regarding public participation, the procedures for the EIA and for the IEP are independent, with the
EIA public participation procedure coming in the first place, and afterwards taking place the IEP
public participation procedure. In the case of the IEP there is no public consultation meeting.
INTEGRATED ENVIRONMENTAL PERMIT PROCEDURE
Developer
Art. 14: Application form
MoEU/permits department
(Permit-related info + EIA report art. 11 +
Seveso notification)
Seveso notification indicating
Seveso category IF NEEDED
MoEU/inspection department
Stakeholders /
general public
Art. 15: Competent Authority
10 working days
EIA report (corresponding to
art. 11 of EIA By-law) IF
NEEDED
Allegations throoughout
the whole process forl public
Art .16: Public information
File available 15
working days
10 working
days
Art. 17: Obtaining reports issued by different
Competent Authorities or departments
120 working
days
Art. 18: Assessment of the project as a whole
EIA + Environmental Permit
20
working
days
- Reports of the Municipality
- Final reports on:
• the different waste water discharges
• wastes
• noise control
• air emissions
• groundwater and soil
• Final report & Decision on EIA (IF
NEEDED)
- Health protection buffer zone (IF
NEEDED)
- WWTP design approval
- Ground water search and use permit (if
no EIA needed)
- Establishment permit (IF NEEDED)
Art. 18: Draft Decision of
Integrated Environmental Permit
Art. 19: Plea of allegations
Competent Administrations & Public
Art. 19: Forwarding allegations to
relevant competent authorities
15 working days
5 working days
15 working days
Art. 19: Forwarding allegations to authorities
related to reports, and elaboration of
comments by these authorities
Art. 20: Assessment of allegations by the Competent Authority
Art. 20: Int. Env. Permit by the Competent Authority (specifying conditions
to be fulfilled to keep its validity after Verification of compatibility)
Art. 22: Notification to the
developer
Art. 22: Publication
20 working days
Art. 20: Denied
240 working days this part of the procedure
Rectify the lack
of information
10 working days
HOW TO COORDINATE THE CONTENTS OF THE EIA FINAL DECISION AND THE
IEP:
PRELIMINARY GENERAL CONSIDERATIONS:
The EIA procedure must be, at least partially (specially in its last steps), coordinated and forming part
of the IEP procedure, and the EIA final decision should be included as an Annex to the contents of the
IEP.
First of all, in order to guarantee a coherence between the information demands related to the EIA
and the IEP procedures, the only way to achieve that goal is that all reports (EIA-related and IEPrelated) are requested by and received through the same “window”, and the staff working in that
“window” should keep track of the different reporting requests and information received, in order to
avoid duplicities. An agreement should be reached between the EIA and environmental permitting
authorities regarding who will be responsible of that “window” (in EU countries it is usually the
environmental permitting authority).
The conditions set out in the EIA final decision should not be a function of change of technologies (as
opposed to an IEP, where ELVs must be a function of available technologies, and the permit must be
renewed in response to the emergence of new technologies). BATs should not be analyzed during
the EIA procedure.
To avoid conflicts between the contents of the IEP and the EIA final decision, the EIA procedure
should focus in the aspects related to the construction phase, and to the dismantling phase of the
installation, while the environmental protection requirements during the stage of operation should
be addressed by the IEP, which will also impose requirements to ensure an appropriate soil status
after the dismantling. By doing this, in case that the installation undergoes any modification related
to its technological processes and operation, there will be need only to modify the IEP, while the EIA
can remain unchanged.
During the IEP procedure, there is a stage where the team in charge of coordinating the preparation
of the IEP has to make a global assessment of draft EIA Decision + sector reports in order to prepare
the draft IEP. If at this stage it is detected that there is a conflict between the conditions stated in the
draft EIA Decision and the ones which should be included in the IEP, a meeting should be held
between EIA and IEP experts to solve the incompatibilities, and if no agreement is reached, the
General Director for EIA, permits & inspections should take a final decision based on the opinions of
both groups of experts.
Nevertheless, if the Competent Authority considers that the EIA final decision has to include some
requirements for the installation’s operational stage to ensure the fulfillment of some environmental
quality standards, then the EIA final decision should state in the corresponding sections that “the
emission limit values or conditions imposed must be considered as “minimum requirements”, and
the emissions of the installation will have, in any case, to respect the emission limit values
established in the IEP”.
SPECIFIC ASPECTS WHERE COORDINATION EIA-IEP HAS TO BE ENSURED:
In order to avoid conflicts between the contents of the EIA Decision and the IEP, at least the
following aspects must be taken into account by both the EIA and IEP experts, and they should be
addressed in the meeting between them within the stage of the global assessment of draft EIA
Decision + sector reports:
1. Preliminary situation for new installation.
2. Operation conditions (including Emission Limit Values (ELVs)).
3. Planning of the environmental monitoring operations and inspections
These topics are discussed in detail below.
1.- PRELIMINARY SITUATION.
For new installation (as in our case under study):
This “environmental starting status” can be fixed by the EIA experts in their report through the
imposition of different studies and measurements, in order to know the initial status of the area
where the installation is proposed to be built and the impact that such construction would have. It is
also possible that the EIA department has its own previous studies of that area.
This kind of studies are usually carried out in order to make the modelling. Before the construction
stage, these studies are elaborated in order to allow a detailed knowledge of the installation’s future
impacts. Independently of the origin of such studies (the different departments or the operator),
their results allow knowing the area vulnerability.
These studies are very important in order to establish the admissible impacts of the facilities. A
careful analysis is needed and it is highly recommendable a coordinated work between the EIA and
IEP Competent Authorities. This part of the report should be analyzed by both departments during
the suggested meeting.
(Obviously, if as a result of these studies, the EIA experts think that the facility will obtain a negative
EIA Decision, they must notify that as soon as possible to the IEP experts).
That will allow that the same conditions are taken under consideration when issuing IEP and EIA.
It can often happen that the EIA experst include operation and constructive conditions in its own
assessment. This, in practice, causes problems in the coordination of the permit because, as
mentioned before, it can imply difficulties in the establishment and updating of permit conditions
ensuring compliance with BAT AELs, which is a basic goal of the draft By-Law on IEP (derived from the
Industrial Emissions Directive 2010/75/EU).
It is important that the EIA Decision does not include constructive or operation conditions neither
ELVs, avoiding to invade the scope of the IEP. In this sense, the EIA Decision must always be written
including a mention as “In addition, the operator will have in any case to fulfill the conditions that
shall be imposed in the IEP”.
The goal of the EIA procedure consists in evaluating the feasibility of the facility. Therefore, in case it
includes ELVs they must be a “minimum” level of protection that, afterwards, the IEP may make
more stringent in order to fulfill the compulsory BAT AELs.
Additionally, It is necessary to remind that those BATAELs are based, not only on the basis of
environment protection, but also to guarantee a common level playing field among different facilities
of a given sector within the countries affected by the IED.
3.-PLANNING OF THE MONITORING OPERATIONS AND INSPECTIONS.
An important feature of the permit, apart from the ELVs, is the Monitoring and Inspection Plan.
The following aspects are an essential part of the integrated permit:
-
Scope of measurements.
Periodicity of measurements.
Internal and external monitoring actions (carried out by the owner, by the competent
authorities or by external authorised control organisms or companies)
Monitoring (if it is necessary) scope and type of analysers and monitoring equipment.
Notifications to the competent authority. (Malfunction detections, emissions that exceed
any limit, etc.)
The IEP experts, in the global assessment stage, will include all the monitoring requirements
(including the ones stated in the EIA Decision), avoiding redundant demands, ensuring an efficient
global monitoring and, during the planned and suggested meeting with the EIA authority, the
possible disagreements should be considerably reduced.
The final decision, if some disagreement persists, should be under the responsibility of a high level
manager above both groups of experts (EIA & IEP).
.
Permit with introductory note
Pollution Prevention and Control (England & Wales) Regulations 2000
ConocoPhillips Ltd
Humber Refinery
Eastfield Road
South Killingholme
North Lincolnshire
DN40 3DW
Permit number
UP3230LR
ConocoPhillips Ltd
Permit Number UP3230LR
Introductory note
This introductory note does not form a part of the permit
The main features of the installation are as follows.
The Humber Refinery is located at South Killingholme in North Lincolnshire and is operated by
ConocoPhillips Ltd. The refinery primarily processes sweet crudes for the production of fuels and
petroleum coke.
The main environmental releases from the site to air are Sulphur Dioxide, Oxides of Nitrogen,
Particulate Matter and Volatile Organic Compounds. Conditions within the permit have been set to
ensure the permitted operation can comply with environmental standards relating to local receptors.
Releases to water are minimised by the use of a three stage effluent treatment plant, and by
recycling this effluent as a raw water feed to an adjacent combined heat and power station.
Status Log of the permit
Detail
Date
Response Date
Application UP3230LR
Duly made 24/08/06
Additional Information requested
08/12/06
Extension to submission date received
05/01/07
Extension agreed
10/01/07
Additional Information received
08/02/07
Additional Information requested
03/04/07
14/05/07
24/8/07
Extension to determination date requested
25/10/07 and 09/11/07
Extension agreed
30/10/07 and 12/11/07
Permit determined
14/12/07
Superseded or Partially Superseded Licences/Authorisations/Consents relating to this installation
Holder
ConocoPhillips Ltd
Reference Number
AY3385 (and variation BD9114)
AA3336 (and variations AK2785,
AU2816)
AF8173 (and variations AL5046,
AP7628, AU5050, AW7789
BB6904, BE5637, BE8725
BG8572, BJ8642, BQ4491
BU5348, BY0216)
Page ii
Date of Issue
01/05/97
30/11/92
Fully or Partially Superseded
Fully superseded
Fully superseded
25/10/93
Fully superseded
last variation
issued 27/11/04
Other existing Licences/Authorisations/Registrations relating to this site
Holder
Reference Number
Date of issue
ConocoPhillips Ltd
WML 55/19/148B
EA Ref 70818
18/12/87
End of Introductory Note
Page iii
Permit
Pollution Prevention and Control
(England and Wales) Regulations 2000
Permit
Permit number
UP3230LR
The Environment Agency (the Agency) in exercise of its powers under Regulation 10 of the Pollution
Prevention and Control (England and Wales) Regulations 2000 (SI 2000 No 1973) hereby authorises
ConocoPhillips Ltd (“the operator”),
whose registered office is
Portman House
2 Portman Street
London
W1H 6DU
company registration number 00529086
to operate an installation at
Humber Oil Refinery
Eastfield Road
South Killingholme
North Lincolnshire
DN40 3DW
to the extent authorised by and subject to the conditions of this permit.
Signed
Date
14/12/2007
T Ruffell
Authorised to sign on behalf of the Agency
Page 1
Conditions
1
Management
1.1
General management
1.1.1
The activities shall be managed and operated:
(a)
in accordance with a management system, which identifies and minimises risks of
pollution, including those arising from operations, maintenance, accidents, incidents
and non-conformances and those drawn to the attention of the operator as a result of
complaints; and
(b)
by sufficient persons who are competent in respect of the responsibilities to be
undertaken by them in connection with the operation of the activities.
1.1.2
Records demonstrating compliance with condition 1.1.1 shall be maintained.
1.1.3
Any person having duties that are or may be affected by the matters set out in this permit shall
have convenient access to a copy of it kept at or near the place where those duties are carried
out.
1.2
Accident management plan
1.2.1
The operator shall:
(a)
maintain and implement an accident management plan;
(b)
review and record at least every 4 years or as soon as practicable after an accident,
(whichever is the earlier) whether changes to the plan should be made;
(c)
make any appropriate changes to the plan identified by a review.
1.3
Energy efficiency
1.3.1
The operator shall:
1.4
1.4.1
(a)
take appropriate measures to ensure that energy is used efficiently in the activities;
(b)
review and record at least every 4 years whether there are suitable opportunities to
improve the energy efficiency of the activities; and
(c)
take any further appropriate measures identified by a review.
Efficient use of raw materials
The operator shall:
(a)
take appropriate measures to ensure that raw materials and water are used efficiently
in the activities;
(b)
maintain records of raw materials and water used in the activities;
(c)
review and record at least every 4 years whether there are suitable alternative
materials that could reduce environmental impact or opportunities to improve the
efficiency of raw material and water use; and
(d)
take any appropriate further measures identified by a review.
Page 2
1.5
1.5.1.
1.6
1.6.1.
Avoidance, recovery and disposal of wastes produced
by the activities
The operator shall:
(a)
take appropriate measures to ensure that waste produced by the activities is avoided or
reduced, or where waste is produced it is recovered wherever practicable or otherwise
disposed of in a manner which minimises its impact on the environment;
(b)
review and record at least every 4 years whether changes to those measures should be
made; and
(c)
take any further appropriate measures identified by a review.
Site security
Site security measures shall prevent unauthorised access to the site, as far as practicable.
.
2.
Operations
2.1
Permitted activities
2.1.1
The operator is authorised to carry out the activities specified in schedule 1 table S1.1 (the
“activities”).
2.2
The site
2.2.1
The activities shall not extend beyond the site, being the land shown edged in green on the site
plan at schedule 2 to this permit.
2.3
Operating techniques
2.3.1
The activities shall, subject to the conditions of this permit, be operated using the techniques
and in the manner described in the documentation specified in schedule 1 table S1.2, unless
otherwise agreed in writing by the Agency.
2.3.2
No raw materials or fuels listed in schedule 3 table S3.1 shall be used unless they comply with
the specifications set out in that table.
2.3.3
Waste shall only be accepted if:
2.3.4
(a)
it is of a type and quantity listed in schedule 3 table S3.2, and
(b)
it conforms to the description in the documentation supplied by the producer and
holder.
Records shall be kept of all waste accepted onto the site.
.
2.4
Off-site conditions
2.4.1
There are no off-site conditions under this section.
Page 3
2.5
Improvement programme
2.5.1
The operator shall complete the improvements specified in schedule 1 table S1.3 by the date
specified in that table unless otherwise agreed in writing by the Agency.
2.5.2
Except in the case of an improvement which consists only of a submission to the Agency, the
operator shall notify the Agency within 14 days of completion of each improvement.
2.6
Pre-operational conditions
2.6.1
There are no pre-operational conditions in this permit.
2.7
Closure and decommissioning
2.7.1
The operator shall maintain and operate the activities so as to prevent or where that is not
practicable, to minimise, any pollution risk on closure and decommissioning.
2.7.2
The operator shall maintain a site closure plan which demonstrates how the activities can be
decommissioned to avoid any pollution risk and return the site to a satisfactory state.
2.7.3
The operator shall carry out and record a review of the site closure plan at least every 4 years.
2.7.4
The site closure plan (or relevant part thereof) shall be implemented on final cessation or
decommissioning of the activities or part thereof.
2.8
Site protection and monitoring programme
2.8.1
The operator shall, within 2 months of the issue of this permit, submit a site protection and
monitoring programme.
2.8.2
The operator shall implement and maintain the site protection and monitoring programme and
shall carry out and record a review of it at least every 4 years.
3.
Emissions and monitoring
3.1
Emissions to water, air or land
3.1.1
There shall be no point source emissions to water, air or land except from the sources and
emission points listed in schedule 4 tables S4.1 and S4.2.
3.1.2
The limits given in schedule 4 shall not be exceeded.
3.1.3
Total annual emissions from the emission point(s) set out in tables schedule 4 S4.1 and S4.2 of
a substance listed in schedule 4 tables S4.4a and S4.4b shall not exceed the relevant limit in
tables S4.4a and S4.4b.
3.2
Transfers off-site
3.2.1
Records of all the wastes sent off site from the activities, for either disposal or recovery, shall be
maintained.
Page 4
3.3
Fugitive emissions of substances
3.3.1
Fugitive emissions of substances (excluding odour, noise and vibration) shall not cause
pollution. The operator shall not be taken to have breached this condition if appropriate
measures, including those specified in schedule 1 table S1.4, have been taken to prevent or
where that is not practicable, to minimise, those emissions.
3.3.2
All liquids, whose emission to water or land could cause pollution, shall be provided with
secondary containment, unless the operator has used other appropriate measures to prevent or
where that is not practicable, to minimise, leakage and spillage from the primary container.
3.4
Odour
3.4.1
Emissions from the activities shall be free from odour at levels likely to cause annoyance outside
the site, as perceived by an authorised officer of the Agency, unless the operator has used
appropriate measures, including those specified in schedule 1 table S1.5, to prevent or where
that is not practicable to minimise the odour.
3.5
Noise and vibration
3.5.1
Emissions from the activities shall be free from noise and vibration at levels likely to cause
annoyance outside the site, as perceived by an authorised officer of the Agency, unless the
operator has used appropriate measures, including those specified in schedule 1 table S1.6, to
prevent or where that is not practicable to minimise the noise and vibration.
3.6
Monitoring
3.6.1
The operator shall, unless otherwise agreed in writing by the Agency, undertake the monitoring
specified in the following tables in schedule 4 to this permit:
(a)
point source emissions specified in tables S4.1 and S4.2;
(b)
process monitoring specified in table S4.8
3.6.2
The operator shall maintain records of all monitoring required by this permit including records of
the taking and analysis of samples, instrument measurements (periodic and continual),
calibrations, examinations, tests and surveys and any assessment or evaluation made on the
basis of such data.
3.6.3
Monitoring equipment, techniques, personnel and organisations employed for the emissions
monitoring programme specified in condition 3.6.1 shall have either MCERTS certification or
MCERTS accreditation (as appropriate) unless otherwise agreed in writing by the Agency.
3.6.4
Permanent means of access shall be provided to enable sampling/monitoring to be carried out
in relation to the emission points specified in schedule 4 tables S4.1 and S4.2 unless otherwise
specified in that schedule.
3.6.5
Within 6 months of the issue of this permit (unless otherwise agreed in writing by the Agency)
the site reference data identified in the site protection and monitoring programme shall be
collected and submitted to the Agency.
Page 5
3.7
Monitoring for the purposes of the Large Combustion
Plant Directive
3.7.1
All LCP monitoring required by this permit shall be carried out in accordance with the provisions
of Annex VIII of the Large Combustion Plant Directive.
3.7.2
If the monitoring results for more than 10 days a year are invalidated within the meaning set out
in Schedule 7, the Operator shall:
(a)
within 28 days of becoming aware of this fact, review the causes of the invalidations
and submit to the Agency for approval, proposals for measures to improve the
reliability of the continuous measurement systems, including a timetable for the
implementation of those measures; and
(b)
implement the approved measures.
3.7.3
Continuous measurement systems on emission points from the LCP shall be subject to quality
control by means of parallel measurements with reference methods at least once every calendar
year.
3.7.4
Unless otherwise agreed in writing by the Agency in accordance with condition 3.7.5 below, the
operator shall carry out the methods, including the reference measurement methods, to use and
calibrate continuous measurement systems in accordance with the appropriate CEN standards.
3.7.5
If CEN standards are not available, ISO standards, national or international standards which will
ensure the provision of data of an equivalent scientific quality shall be used, as agreed in writing
with the Agency.
3.7.6
Where required by a condition of this permit to check the measurement equipment the operator
shall submit a report to the Agency in writing, within 28 days of the completion of the check.
4.
Information
4.1
Records
4.1.1
All records required to be made by this permit shall:
(a)
be legible;
(b)
be made as soon as reasonably practicable;
(c)
if amended, be amended in such a way that the original and any subsequent
amendments remain legible, or are capable of retrieval;
(d)
be retained, unless otherwise agreed in writing by the Agency, for at least 6 years from
the date when the records were made, or in the case of the following records until
permit surrender:
(i)
the site protection and monitoring programme.
4.1.2
Any records required to be made by this permit shall be supplied to the Agency within 14 days
where the records have been requested in writing by the Agency.
4.1.3
All records required to be held by this permit shall be held on the site and shall be available for
inspection by the Agency at any reasonable time.
Page 6
4.2
Reporting
4.2.1
A report or reports on the performance of the activities over the previous year shall be submitted
to the Agency by 31 January (or other date agreed in writing by the Agency) each year. The
report(s) shall include as a minimum:
4.2.2
(a)
a review of the results of the monitoring and assessment carried out in accordance with
this permit against the relevant assumptions, parameters and results in the assessment
of the impact of the emissions submitted with the application;
(b)
where the operator's management system encompasses annual improvement targets,
a summary report of the previous year's progress against such targets;
(c)
the annual production /treatment data set out in schedule 5 table S5.2;
(d)
the performance parameters set out in schedule 5 table S5.3 using the forms specified
in table S5.4 of that schedule;
(e)
details of any contamination or decontamination of the site which has occurred.
Within 28 days of the end of the reporting period the operator shall, unless otherwise agreed in
writing by the Agency, submit reports of the monitoring and assessment carried out in
accordance with the conditions of this permit, as follows:
(a)
in respect of the parameters and emission points specified in schedule 5 table S5.1;
(b)
for the reporting periods specified in schedule 5 table S5.1 and using the forms
specified in schedule 5 table S5.4 ; and
(c)
giving the information from such results and assessments as may be required by the
forms specified in those tables.
4.2.3
The operator shall, unless notice under this condition has been served within the preceding 4
years, submit to the Agency, within 6 months of receipt of a written notice, a report assessing
whether there are other appropriate measures that could be taken to prevent, or where that is
not practicable, to minimise pollution.
4.2.4
All reports and notifications required by the permit shall be sent to the Agency using the contact
details supplied in writing by the Agency
4.2.5
A summary report of the waste types and quantities accepted onto the site shall be made for
each quarter during which the total amount accepted exceeds 100 tonnes of non-hazardous
waste or 10 tonnes of hazardous waste. It shall be submitted to the Agency within one month of
the end of the quarter and shall be in the format required by the Agency.
4.2.6
The results of reviews and any changes made to the site protection and monitoring programme
shall be reported to the Agency, within 1 month of the review or change.
4.3
Notifications
4.3.1
The Agency shall be notified without delay following the detection of:
(a)
any malfunction, breakdown or failure of equipment or techniques, accident, or fugitive
emission which has caused, is causing or may cause significant pollution;
(b)
the breach of a limit specified in the permit;
(c)
any significant adverse environmental effects
Page 7
4.3.2
Any information provided under condition 4.3.1 shall be confirmed by sending the information
listed in schedule 6 to this permit within the time period specified in that schedule.
4.3.3
Prior written notification shall be given to the Agency of the following events and in the specified
timescales:
(a)
as soon as practicable prior to the permanent cessation of any of the activities;
(b)
cessation of operation of part or all of the activities for a period likely to exceed 1 year;
and
(c)
resumption of the operation of part or all of the activities after a cessation notified under
(b) above.
4.3.4
The Agency shall be given at least 14 days notice before implementation of any part of the site
closure plan.
4.3.5
Where the Agency has requested in writing that it shall be notified when the operator is to
undertake monitoring and/or spot sampling, the operator shall inform the Agency when the
relevant monitoring is to take place. The operator shall provide this information to the Agency at
least 14 days before the date the monitoring is to be undertaken.
4.3.6
The Agency shall be notified within 14 days of the occurrence of the following matters, except
where such disclosure is prohibited by Stock Exchange rules:
4.3.7
(a)
any change in the operator’s trading name, registered name or registered office
address;
(b)
any change to particulars of the operator’s ultimate holding company (including details
of an ultimate holding company where an operator has become a subsidiary); and
(c)
any steps taken with a view to the operator going into administration, entering into a
company voluntary arrangement or being wound up.
Where the operator has entered into a direct participant agreement in the emissions trading
scheme which covers emissions relating to the energy consumption of the activities, the
operator shall notify the Agency within one month of:
(a)
a decision by the operator to withdraw from or the Secretary of State to terminate that
agreement.
(b)
a failure to comply with an annual target under that agreement at the end of the trading
compliance period.
Notification of closure of Large Combustion Plant
4.3.8
From 1 January 2008 the operator shall inform the Agency in writing of the intended closure of
any LCP, giving as much notice as possible before closure.
4.4
Interpretation
4.4.1
In this permit the expressions listed in schedule 7 shall have the meaning given in that schedule.
Page 8
Schedule 1 - Operations
Table S1.1 activities
Activity listed in Schedule 1
of the PPC Regulations
Description of specified
activity
Limits of specified activity
S1.1 A(1) (a)
Burning any fuel in an
appliance with a rated
thermal input of 50MW or
more
Refinery fuel gas (including the cryogenic unit) and natural gas
supply systems to combustion units and any associated
activities necessary to maintain the operation of the plant and
fuel supplies through to the discharge of exhaust gases from
the stacks, abatement plant and the export of steam to the
steam systems, including:
(i)
S1.2 A(1) (g)
Refining mineral oil
(Primary operations)
From feed to oil refining unit to use, including each of the
following units:
(i)
(ii)
#3 vacuum distillation unit (#3 VDU), including
process heater
(iv)
Gas oil hydrodesulphurisation unit (GOHDS),
including process heater
(v)
Heavy oil filtration unit
#1 Calciner including coke handling, storage and
rail/road loading, and petroleum coke unloading,
handling, storage and loading area (including flare
pad)
(vii)
pad)
(viii)
pad)
(ix)
Virgin hydrodesulphurisation unit (VHDS), including
process heaters
(x)
Cracked hydrodesulphurisation unit (CHDS),
including process heaters
(xi)
Diesel hydrodesulphurisation unit (DHDS), including
process heaters
Gasoline hydrodesulphurisation unit (GHDS),
including process heater
(xii)
(xiii)
Penex unit, including process heater
(xiv)
Saturated gas plant (SGP)
Cracked gas plant (CGP) including CPU Merox ,
Selective Hydrogenation Process (SHP-2), and flare
gas recovery compressors
(xv)
(xvi)
Catalytic reforming unit #2 (CRU-2), including
process heaters and hydrogen system
(xvii)
Catalytic reforming unit #3 (CRU-3), including
process heaters and hydrogen system
(xviii)
Pressure swing adsorber (PSA)
Aromatics extraction unit (AEU)
Fluid catalytic cracking unit (FCCU), process
heaters, FCCU gasoline heart-cut treatment (Minalk
(xix)
(xx)
Page 9
process heater
process heater
(iii)
(vi)
Onsite 24MWe CHP unit (GTA 711, GTA 712, GTA 713
and GTA 714)
system) and selective hydrogenation unit
(xxi)
Propylene recovery unit (PRU) including PRU
Merox and selective hydrogenation process (SHP1)
(xxii)
Vapour recovery unit (VRU) including VRU Merox
(Minalk)
(xxiii)
Alkylation Unit including process heater and
Butamer unit
(xxiv)
Thermal cracking unit (TCU) including process
heater
GTA 706
(xxv)
S1.2 A(1) (h) (i)
S1.2 A(1) (j)
Refining mineral oil
(Secondary operations –
oil movements and
blending)
From receipt of feed, through blending (where necessary) to
feed, intermediate and product storages and export including:
liquified petroleum gases, white oils (including rail loading of
petrol/diesel and petrol vapour recovery unit), heavy gas oils
and other black oils, slops, etc. in support of the above primary
operations.
The handling, storage and
physical/ thermal treatment
of crude oil
From receipt and storage of crude (including unloading from
road tankers and blending of slops) to operation of crude
distillation units, including:
Carbonisation activities
applied to oils or other
carbonaceous materials.
(i)
#1 Crude topping unit (#1 CTU), process heater and
associated feed and product system for this activity
(ii)
#2 Crude topping unit (#2 CTU), process heater,
kerosene treatment and associated feed and
product system for this activity
From feed to unit to discharge to further processing including:
(i)
#1 Coker, process heaters and green coke storage
pit
(ii)
#2 Coker, process heaters and green coke storage
pit
S4.1 A(1)(a) (i)
Producing organic
chemicals, such as
aromatic hydrocarbons
Hydro de-alkylation unit (HDA), for the manufacture of benzene,
process heaters and associated feed and product
storage/export system for this activity
S4.1 A(1) (a) (ii)
Producing organic
compounds containing
oxygen, such as ethers.
From receipt of raw materials to the manufacture, storage and
despatch of finished product. (including the cleaning of the
process plant, operation of abatement systems and the storage
and handling of waste arising from the process). Production
plants covered include:
(a) Dimethylether unit (DME), unloading and storage of
methanol feed and storage and loading of product.
S4.2 A(1) (a) (v)
Producing inorganic
chemicals such as nonmetals (e.g. sulphur)
Sulphur recovery unit plant (with associated amine systems,
amine recovery unit, sour water stripper units), including:
(i)
#1 Sulphur recovery unit (#1 SRU) with tail-gas
incineration and storage/loading of products
(ii)
#2 Sulphur recovery unit (#2 SRU) with SuperClaus
unit, tail gas incineration and storage/loading of
products
S5.3 A(1) (a)
Disposal of hazardous
waste in a facility with a
capacity of more than 10
tonnes per day (by
biological treatment)
Treatment in the main biological effluent treatment plant (ETP),
including oil water separators, IAF units, activated sludge unit,
#1, #2, #3 and Alkylation holding ponds, storage of sludge and
waste receipt detailed in table 3.2.
S5.3 A(1) (c) (ii)
Disposal of non-hazardous
waste in a facility with a
capacity of more than 50
tonnes per day by physico
-chemical treatment.
Physical treatment of South tank farm (STF) surface waters in
oil-water separator, including bund/surface water collection
systems and holding pond
Page 10
Directly Associated Activity
Flaring of gases
Burning of sour and sweet gases at
flares.
Flare headers, knock-out pots and flare stacks
and any ancillary equipment. Includes closed
Blowdown system.
Cooling water systems
Systems used for cooling.
All cooling water systems including storage,
pipelines and equipment, to discharge to ETP.
Lagoons
The holding or temporary storage of
water, effluents or oil-based liquids for
settling (sedimentation) or other
purposes
The feed point to the lagoon(s), the lagoon(s) and
its drainage point.
Surface water drainage
.
Collection and handling of surface
waters within installation
Handling and storage of site drainage until
discharge to the site waste water treatment
system or to discharge off-site.
Water treatment
All water treatment activities
From receipt of raw materials to dispatch to
effluents to sewer or site waste water treatment
system.
Table S1.2 Operating techniques
Description
Parts
Date Received
Application
The response to section 2.1 to 2.2.
24/08/06
Response to Schedule 4
Notice dated 08/12/06
Response to Q1 – 2 subject to the limits set in Schedule 4.1
Response to Q3 – 5 subject to the conditions in schedule 1.3
09/02/07
09/02/07
Response to Schedule 4
Notice dated 03/04/07
Response to FCCU Regenerative Scrubbing BAT review.
15/05/07
Additional information
Application Resubmission – The revised response to sections 2.1 to 2.2,
and consolidation of the Schedule 4 responses.
24/08/07
.
Page 11
Table S1.3 Improvement programme requirements
Reference
Requirement
Date
IC1
A written procedure shall be submitted to the Agency detailing the measures to be used so
that monitoring equipment, personnel and organisations employed for the emissions to air
monitoring programme shall have either MCERTS certification or accreditation in
accordance with condition 3.6.3. The notification requirements of condition 2.5.2 shall be
deemed to have been complied with on submission of the procedure.
01/04/08
IC2
IC3
IC4
IC5
IC6
The procedure shall be implemented by the operator from the date of approval by the
Agency
A written plan shall be submitted to the Agency for approval detailing the results of a
survey of hard-standing, kerbing and secondary containment for raw material,
intermediate, product and waste storage areas and the measures to comply with the
requirements of section 2.2.5 of TGN S 1.02. Where appropriate the plan shall contain
dates for the implementation of individual measures. The notification requirements of
condition 2.5.2 shall be deemed to have been complied with on submission of the plan.
01/04/09
The plan shall be implemented by the operator from the date of approval by the Agency.
A written plan shall be submitted to the Agency for approval detailing the results of a
01/07/10
survey of bunding and other secondary containment measures for raw materials,
intermediates, products and waste storage areas and the measures to meet the
requirements of section 2.2.2 and 2.2.3 of Sector Guidance Note S 1.02. Where
appropriate the plan shall contain dates for the implementation of individual measures. The
notification requirements of condition 2.5.2 shall be deemed to have been complied with on
submission of the plan.
A written plan shall be submitted to the Agency for approval detailing the measures to be
taken to achieve a sulphur recovery efficiency of 99.5% in accordance with the Sector
Guidance Note S 1.02. The plan shall contain dates for the implementation of individual
measures. The notification requirements of condition 2.5.2 shall be deemed to have been
complied with on submission of the plan.
A written plan shall be submitted to the Agency for approval detailing the measures to be
taken to achieve a reduction in the sulphur dioxide emission concentration from the FCCU
regenerator. Where appropriate the plan shall contain dates for the implementation of
individual measures. The notification requirements of condition 2.5.2 shall be deemed to
have been complied with on submission of the plan.
01/10/08
01/03/08
A written plan shall be submitted to the Agency for approval detailing the work to be 01/07/09
undertaken to carry out Leak Detection and Repair across all plant and pipework at the
refinery installation. The plan shall include work necessary to bring the LDAR monitoring
status at the installation to Tier 1, Tier 2 and Tier 3 versus the USEPA Method 21, all within
4 years.
Where appropriate the plan shall contain dates for the implementation of individual
IC7
IC8
A written procedure shall be submitted to the Agency detailing the measures to be used so
that monitoring equipment and sampling for the emissions to water monitoring programme
shall have either MCERTS certification or accreditation in accordance with condition 3.6.3.
The notification requirements of condition 2.5.2 shall be deemed to have been complied
with on submission of the procedure.
01/04/09
The procedure shall be implemented by the operator from the date of approval iby the
Agency
A written plan shall be submitted to the Agency for approval detailing the measures to be 01/03/09
taken to reduce oxides of nitrogen (NOx) emissions from the refinery installation. Where
appropriate the plan shall contain dates for the implementation of individual measures. The
notification requirements of condition 2.5.2 shall be deemed to have been complied with on
Page 12
IC9
IC10
IC11
IC12
A written plan shall be submitted to the Agency for approval detailing the implementation 01/04/08
programme for continuous monitoring of SO2 and NOx for release points A9 and A11. The
notification requirements of 2.5.2 shall be deemed to have been complied with on
A written evaluation shall be submitted to the Agency for approval detailing the technical 01/04/11
and economic feasibility of installing liquid ring pumps on VDU1 and VDU2. Where
appropriate the plan shall contain dates for the implementation of various measures. The
notification requirements of 2.5.2 shall be deemed to have been complied with on
A written report shall be submitted to the Agency for approval detailing the findings of a 01/04/09
water use audit. Where appropriate the report shall contain dates for the implementation of
individual measures. The notification requirements of 2.5.2 shall be deemed to have been
A written report shall be submitted to the Agency giving details of any hydrocarbon- 01/06/08
containing wastes that are currently disposed of. The report shall include a proposed plan
and programme, for approval by the Agency, for the introduction of any techniques
necessary to ensure the following in relation to the above wastes:
(a) prevention or reduction of waste arisings,
(b) recovery and/or recycling of any wastes that do arise, and
(c) disposal of any wastes for which recovery is technically and economically impossible
is carried out in a way that avoids or reduces any impact on the environment.
IC13
A written evaluation shall be submitted to the Agency for approval detailing the potential 01/04/12
for reuse or recovery for the following waste streams
(a)
(b)
Sodium hydroxide containing sodium naphthenate
Potassium hydroxide containing fluoride
measures. The notification requirements of 2.5.2 shall be deemed to have been complied
with on submission of the plan.
IC14
The plan shall be implemented by the operator from the date of approval by the Agency
A written report shall be submitted to the Agency for approval detailing the ambient Interim response
benzene levels around the installation, and an evaluation made of the the technical and 01/02/09
economic feasibility of options to reduce emissions.
Where appropriate the report shall contain dates for the implementation of individual Final response
measures. The notification requirements of 2.5.2 shall be deemed to have been complied 01/10/09
with on submission of an implementation plan.
IC15
IC16
A written report shall be submitted to the Agency for approval detailing the ambient VOC Interim response
levels other than benzene around the installation for VOCs considered significant in the 01/02/09
application H1 assessment, and an evaluation made of the the technical and economic
feasibility of options to reduce emissions.
Final response
Where appropriate the report shall contain dates for the implementation of individual 01/10/11
measures The notification requirements of 2.5.2 shall be deemed to have been complied
with on submission of an implementation plan
A written evaluation shall be submitted to the Agency for approval detailing the technical 01/04/08
and economic feasibility of improving the dispersion of releases to air from release point
A11.
Page 13
with on submission of the plan.
IC17
A written plan shall be submitted to the Agency for approval detailing the installation of 01/02/08
continuous SO2 and NOx monitors for release points A1, A3 and A5 at the refinery
installation.
The plan shall contain dates for the implementation of individual measures. The notification
requirements of condition 2.5.2 shall be deemed to have been complied with on
IC18
IC 19
A written plan shall be submitted to the Agency for approval detailing the technical and 01/03/08
economic feasibility of returning a FCCU expander back into service.. Where appropriate
the plan shall contain dates for the implementation of individual measures. The notification
requirements of 2.5.2 shall be deemed to have been complied with on submission of the
plan.
A written report shall be submitted to the Agency for approval detailing the measures 01/07/08
proposed to improve the hourly estimation of normalised flue gas volumes from release
points A6, A8, A9 and A11.
Where appropriate the report shall contain dates for the implementation of individual
with on submission of an implementation plan.
Table S1.4 Appropriate measures for fugitive emissions
Measure
Dates
The operator shall maintain a managed LDAR programme for testing potential sources of
fugitive emissions of VOCs from operational plant at the installation, as described in Section
2.2.4 of the application. The operator shall complete repairs and/or carry out other actions to
prevent, or where that is not possible, minimise continued emissions from those sources.
From date of permit issue
Table S1.5 Appropriate measures for odour
Measure
Dates
The operator shall maintain the odour management plan as described in section 2.2.6 of the
application.
From date of permit issue.
practicable after a complaint (whichever is the earlier), whether changes to the plan should be
made and make any appropriate changes to the plan identified by a review.
Table S1.6 Appropriate measures for noise
Measure
Dates
The operator shall maintain the noise management plan as described in section 2.9 of the
application.
From date of permit issue.
practicable after a complaint (whichever is the earlier), whether changes to the plan should be
made and make any appropriate changes to the plan identified by a review.
Page 14
Schedule 2 - Site plan
“Reproduced from the Ordnance Survey map with the permission of the Controller of Her Majesty’s Stationery
Office Crown Copyright 2000. Unauthorised reproduction infringes Crown Copyright and may lead to
prosecution or civil proceedings.”
Page 15
Schedule 3 - Waste types, raw materials and fuel
Table S3.1 Raw materials and fuels
Raw materials and fuel description
Specification
Refinery fuel gas (RFG)
Less than 200 ppmv sulphur as H2S (daily avg)
Table S3.2 Permitted waste types and quantities for Effluent Treatment Plant
Maximum quantity
Rate to be controlled to comply with the limits in Table S4.2
Waste code
Description
05 01 09*
Oily Water Separator Sludge (Tetney and Ocean Terminal)
16 07 08*
Tetney Roof Seal decontamination effluent
16 10 02
Humber LPG Caverns pigging water/Ocean Terminal Tank Water Bottoms
10 01 19
ICHP fuel gas knockout pot condensate
16 10 01*
Ocean Terminal Gasoline tank, water bottoms
Page 16
Schedule 4 – Emissions and monitoring
Table S4.1 Point source emissions to air – emission limits and monitoring requirements
Emission
point ref.
& location
Source
Parameter
Limit (including
unit)
Reference
Period
Monitoring
frequency
Monitoring
standard or
method
A1
ST 101
Sulphur
dioxide
No limit set
Hourly
Continuous
Note 1
BS EN14181
Oxides of
nitrogen
(as NO2)
No limit set Note
2
Annually
Continuous
Note3
BS EN14181
Particulate
No limit set Note
2
Annually
-
Agreed Factor
Sulphur
dioxide
No limit set
Hourly
Continuous
Note 1
Oxides of
nitrogen
(as NO2)
No limit set Note
Average over
sampling period
Annually
Note 9
ISO 10849
Particulate
No limit set
Sulphur
dioxide
No limit set Note 2, 7
Hourly
Continuous
Note 1
BS EN14181
Oxides of
nitrogen
(as NO2)
No limit set Note
2
Annually
Continuous
Note3
BS EN14181
Particulate
No limit set Note
2
Annually
-
Agreed Factor
Sulphur
dioxide
No limit set Note 7
Hourly
Continuous
Note 1
Oxides of
nitrogen
(as NO2)
No limit set
Hourly
Continuous
Note 9
BS EN14181
Particulate
No limit set
-
-
-
Sulphur
dioxide
Hourly
Continuous
Note 1
BS EN14181
Oxides of
nitrogen
(as NO2)
No limit set Note
2
Annually
Continuous
Note3
BS EN14181
2
Annually
-
Agreed Factor
Hourly
Continuous
Note 1
A2
A3
A4
A5
ST 102
ST 201
ST 202
ST 301
Note 2 ,7
Note 7
2
-
-
-
Particulate
No limit set Note
A6
ST3401
Sulphur
dioxide
2000 mg/Nm3
0.33 t/h
Hourly
Continuous
Note 1
A6a
ST 3401
Sulphur
dioxide
Average over
sampling period
6 monthly
BS 6069 - 4.4
LCP
Oxides of
nitrogen
(as NO2)
No limit set Note
2
Average over
sampling period
6 monthly
Note 9
ISO 10849
Particulate
No limit set Note
2
ST3401
Sulphur
dioxide
No limit set
FCCU
Regenerator
Oxides of
nitrogen
(as NO2)
Particulate
A6b
Annually
-
Agreed Factor
Hourly
Continuous
BS EN14181
300 mg/Nm3
Daily
Continuous
BS EN14181
100 mg/Nm3
Daily
Continuous
Dust Density
CEMs
Calibration
BS ISO 9096
Note 11
A7
ST 3501
-
CO
200 mg/Nm3
Daily
Continuous
BS EN14181
Sulphur
dioxide
No limit set
Hourly
Continuous
Note 1
Page 17
Note 7
A8
A9
ST 401
ST 5601
Oxides of
nitrogen
(as NO2)
No limit set Note
Particulate
No limit set
2
Average over
sampling period
-
mg/Nm3
A11
ST 6001
ST 601
ISO 10849
-
-
Sulphur
dioxide
55000
Hourly
Continuous
Note 1
0.42 t/h
Hourly
Continuous
Note 1
Oxides of
nitrogen
(as NO2)
No limit set
-
-
-
Sulphur
dioxide
1700 mg/Nm3
Hourly
Continuous
Notes 1, 6
BS EN14181
0.16 t/h
Hourly
Continuous
Notes 1, 6
BS EN14181
Hourly
Continuous
Note 6
BS EN14181
Daily
Continuous
Dust Density
CEMs
Calibration
BS ISO 9096
Oxides of
nitrogen
(as NO2)
No limit set Note
Particulate
150 mg/Nm3
4
A10
Annually
Note 9
Sulphur
dioxide
35 mg/Nm3
Monthly
Continuous
Note 1
BS EN14181
Oxides of
nitrogen
(as NO2)
300 mg/Nm3
Monthly
Continuous
BS EN14181
Particulate
5 mg/Nm3
Daily
Continuous
Agreed Factor
Hourly
Continuous
Note 1, 6
BS EN14181
Hourly
Continuous
Note 1, 6
BS EN14181
Hourly
Continuous
Note 6
BS EN14181
Continuous
Dust Density
CEMs
Calibration
BS ISO 9096
Sulphur
dioxide
1700
mg/Nm3
0.2 t/h
Oxides of
nitrogen
(as NO2)
No limit set Note
Particulate
150 mg/Nm3
4
Daily
-
A12
ST 602
Particulate
230 mg/Nm3
Daily
Continuous
Dust Density
A13
ST 701
Sulphur
dioxide
No limit set
Hourly
Continuous
Note 1
Oxides of
nitrogen
(as NO2)
No limit set
Average over
sampling period
Annually
Note 9
ISO 10849
Sulphur
dioxide
No limit set
Oxides of
nitrogen
(as NO2)
125 mg/Nm3 Note 8
Particulate
5 mg/Nm3
A14
ST 703
A15
ST801
VOC’s
35
A16
H 4102
Sulphur
dioxide
No limit set
Oxides of
nitrogen
(as NO2)
No limit set
Page 18
Note 7
-
-
-
Daily
Continuous
-
Daily
Continuous
Agreed Factor
Daily
Continuous
Infrared
Absorption
Hourly
Continuous
Note 1
Average over
sampling period
Annually
Note 9
ISO 10849
Note 7
g/m3 Note 5
Note 7
A17
A18
A19
A20
H 571
H 572
H 6301/2
H 6303/4/5
Particulate
No limit set
-
Sulphur
dioxide
No limit set
Oxides of
nitrogen
(as NO2)
No limit set
Particulate
No limit set
Sulphur
dioxide
No limit set
Oxides of
nitrogen
(as NO2)
No limit set
Particulate
No limit set
Sulphur
dioxide
Oxides of
nitrogen
(as NO2)
No limit set Note
2
Particulate
No limit set Note
2
Sulphur
dioxide
No limit set
Oxides of
nitrogen
(as NO2)
No limit set
Note 7
-
Hourly
Continuous
Note 1
Average over
sampling period
Annually
Note 9
ISO 10849
Note 7
-
-
Hourly
Continuous
Note 1
Average over
sampling period
Annually
Note 9
ISO 10849
-
Note 7
-
-
-
Hourly
Continuous
Note 1
Average over
sampling period
6 monthly
BS 6069 - 4.4
Average over
sampling period
6 monthly
Note 9
ISO 10849
Annually
-
Agreed Factor
Hourly
Continuous
Note 1
Average over
sampling period
Annually
Note 9
ISO 10849
Particulate
No limit set
-
-
A21
No 1 Flare
Sulphur
dioxide
0.4 t/h equivalent
15 minutes
-
Note 1
A22
No 3 Flare
Sulphur
dioxide
0.7 t/h equivalent
15 minutes
-
Note 1
A23
H 151
Sulphur
dioxide
No limit set
Hourly
Continuous
Note 1
Oxides of
nitrogen
(as NO2)
No limit set
Average over
sampling period
Annually
Note 9
ISO 10849
Particulate
No limit set
Sulphur
dioxide
No limit set
Oxides of
nitrogen
(as NO2)
No limit set
A24
H 501
-
Note 7
Note 7
-
-
Hourly
Continuous
Note 1
Average over
sampling period
Annually
Note 9
ISO 10849
Particulate
No limit set
-
-
-
A25
PSV3671
HF
No Release
Permitted
-
-
-
A26
PSV3680
Tetrachloro
ethene
No Release
Permitted
-
-
-
A27
PSV T502
Tetrachloro
ethene
No Release
Permitted
-
-
-
A28
AEU PSVs
Benzene
No Release
Permitted
-
-
-
Toluene
No Release
Permitted
-
-
-
A28
W801
A30
W781
HOBD
VOCs
(Class B)
-
-
-
-
No limit set
-
-
-
Page 19
A31
D6305
CR2 Regen
VOCs
(Class B)
No limit set
-
-
-
A32
D6004
CR3 Regen
VOCs
(Class B)
No limit set
-
-
-
A33
ST4401
Amine filtration
Water
vapour
No limit set
-
-
-
A34
D5422
Merox CPU
VOCs
(Class B)
No limit set
-
-
-
A35
D3609
Merox PRU
VOCs
(Class B)
No limit set
-
-
-
A36
Coking/Calciner
silo vents and
solid handling
system vents
Particulate
Non visible
Daily
-
A37
Hydrocarbon
Storage Tank
Vents
VOCs
(Class B)
No limit set
-
-
Note 10
A38
PSVs/PRVs
VOCs
(Class A)
No Release
Permitted
-
-
-
Benzene
No Release
Permitted
-
-
-
Average over
Assessment
Period
Note 1
Continuous estimate of releases based on the method agreed with the Agency. Reference
conditions for normalised flow (3% O2, dry).
Note 2
Releases controlled under the NERP, monitoring for NERP reporting requirements only.
Note 3
NERP reporting basis finalised following completion of condition IC17.
Note 4
Limit to be agreed following completion of condition IC9.
Note 5 Limit does not apply when PSVs 8202/8203/8204 are releasing VOCs.
Note 6 Monitoring method to be revised to BS EN14181 following completion of condition IC9.
Note 7 RFG limit in table 3.1 provides control.
Note 8 A limit of 145 mg/m3 applies during supplementary firing.
Note 9 Monitoring required for compliance with reporting condition 4.2.1 (h)
Note 10 Based on the USEPA method 21.
Note 11 The limit does not apply at start up and shutdown.
Page 20
Table S4.1a Point Source emissions to air – bubble emission limit and monitoring requirements
Release Points Parameter
Sources
Bubble Limit
Reference
Monitoring
frequency
Period
A1-A11
A16-A20
A23-A24
Sulphur Dioxide
FCCU
SRUs
Calciners
Heaters
Hourly
1000 mg/Nm3
Limit applies from
1/1/09. Reporting
in 2008 required.
1.04 t/h
A1-A11
A16-A24
FCCU
SRUs
Calciners
Heaters
Flares
Page 21
1.13 t/h
Continuous
Method
Table S4.1
Note 1 applies
Table S4.2 Point Source emissions to water (other than sewer) – emission limits and monitoring requirements
Emission point
Parameter
Source
Limit
Reference
Monitoring
Monitoring
ref. & location
(incl.
frequency
standard or method
Period
unit)
W1 on site plan in
schedule 2
emission to
Harborough
Marsh Drain
W2a/W2b on site
plan in schedule 2
emission to South
Killingholme Drain
COD
South Tank
Farm
Surface
Water
Oil
125 mg/l
15 mg/l
METH 423
BS ISO 15705-2002
Instantaneous
Monthly
METH 410
IP426
Flow (Dry Weather)
Temperature
16000 m3
Day
Continuous
BS 3680
300C
Hourly
Continuous
Thermometer
pH
5–9
TOC
50 mg/l
Oil
5 mg/l
METH 410
IP426
COD
200 mg/l
METH 423
BS ISO 15705-2002
Ammoniacal
Nitrogen
10 mg/l
METH 414/417
BS6068 2.33 – 1987
ISO7150/2 – 1986
Phenols
Effluent
Treatment
Plant
0.5 mg/l
Meter
Instantaneous
Time related
24h composite
Daily
Weekly
METH 421/422
BS EN 1484:1997
METH 416
BS EN ISO 14402
Fluoride
20 mg/l
METH 426
Hach 8029 –
EPA340.1
Sulphide
0.25 mg/l
METH 415/418
EPA 376.2
Suspended Solids
30 mg/l
METH 407
BS EN 872 – 2005
Cyanide
-
Arsenic
15 µg/l
Cadmium
10 µg/l
Chromium
250 µg/l
Copper
100 µg/l
METH 420
ASTM D2036
BS EN ISO 11969
EPA3015
Instantaneous
Quarterly
BS EN ISO 15586
EPA3015
Lead
250 µg/l
Mercury
0.5 µg/l
EN 13506/EPA3015
Nickel
250 µg/l
Zinc
750 µg/l
BS EN ISO 15586
EPA3015
Page 22
Table S4.4(a) Annual limits
Substance
Medium
Limit (including unit)
Sulphur dioxide 20082015 inclusive
Air
6300 tonnes
Sulphur dioxide 2016
onwards
Air
4500 tonnes
Table S4.4(b) LCPD Annual limits (Excluding start up and shut down except where otherwise stated).
Substance
Medium
Limit (including unit)
Release Points
Particulate matter,
Sulphur dioxide and
Oxides of nitrogen
Air
Assessment year
LCP NERP Limit
01/01/08-31/12/08 and
subsequent years until
31/12/15
Emission allowance
figure shown in the
NERP Register as at 30
April the following year
Particulate matter,
Sulphur dioxide and
Oxides of nitrogen
Air
Assessment year
LCP NERP Limit
01/01/08-31/12/08 and
31/12/15
Emission allowance
figure shown in the
Particulate matter,
Sulphur dioxide and
Oxides of nitrogen
Air
Assessment year
LCP NERP Limit
01/01/08-31/12/08 and
31/12/15
Emission allowance
figure shown in the
Particulate matter,
Sulphur dioxide and
Oxides of nitrogen
Air
Assessment year
LCP NERP Limit
01/01/08-31/12/08 and
31/12/15
Emission allowance
figure shown in the
Particulate matter,
Sulphur dioxide and
Oxides of nitrogen
Air
Assessment year
LCP NERP Limit
01/01/08-31/12/08 and
31/12/15
Emission allowance
figure shown in the
A1 – LCP Ref 9
A5 – LCP Ref 10
A3 – LCP Ref 11
A6a – LCP Ref 12
A19 – LCP Ref 13
Table S4.8 Process monitoring requirements
Emission point reference or
source or description of point
of measurement
Parameter
Monitoring
frequency
Monitoring
standard or
method
SRU Survey
Performance Evaluation
Every 2 years
Not
applicable
RFG on-line analyser
H2S
Continuous
Not
applicable
Page 23
Other specifications
Schedule 5 - Reporting
Parameters, for which reports shall be made, in accordance with conditions of this permit, are listed
below.
Table S5.1 Reporting of monitoring data
Parameter
Emission or monitoring
point/reference
Reporting period
Period begins
Emissions to air – sulphur dioxide
Parameters as required by condition 3.6.1.
A1-A11, A13, A14, and A16A24.
Every 3 months
01/01/08
Emissions to air – oxides of nitrogen
A1-A11, A13, A14, A16-A20
and A23-A24
Every 3 months
01/01/08
Emissions to air – particulate matter
A1-A7, A9-A12, A14, A16-A20
and A23-A24
Every 3 months
01/01/08
Emissions to air – VOCs
A15
Every 12 months
01/01/08
Emissions to water – oil
Parameters as required by condition 3.6.1
W1 and W2a/b
Every 3 months
01/01/08
Emissions to water – COD
W1 and W2a/b
Every 3 months
01/01/08
Emissions to water – Flow
W2a/b
Every 3 months
01/01/08
Emissions to water – Temperature
W2a/b
Every 3 months
01/01/08
Emissions to water – pH
W2a/b
Every 3 months
01/01/08
Emissions to water – TOC
W2a/b
Every 3 months
01/01/08
Emissions to water – Suspended Solids
W2a/b
Every 3 months
01/01/08
Emissions to water – Ammoniacal Nitrogen
W2a/b
Every 3 months
01/01/08
Emissions to water – Phenols
W2a/b
Every 3 months
01/01/08
Emissions to water – Sulphides
W2a/b
Every 3 months
01/01/08
Emissions to water – Fluorides
W2a/b
Every 3 months
01/01/08
Emissions to water – Cyanides
W2a/b
Every 3 months
01/01/08
Emissions to water – Heavy Metals
W2a/b
Every 3 months
01/01/08
Page 24
Table S5.2: Annual production/treatment
Parameter
Units
Road and other transport fuels
Tonnes
Non-transport / heating fuels
Tonnes
Chemical / petrochemical feedstocks
Tonnes
Bitumen / petcoke / other heavy-end products
Tonnes
Table S5.3 Performance parameters
Parameter
Frequency of assessment
Units
LCPD Annex VIII(B) mass releases of SO2, NOx and Dust
Annually
Tonnes
LCPD Annex VIII(B) energy useage by fuel type
Annually
GJ
LCPD NERP mass releases of SO2, NOx and Dust
Annually
Tonnes
LCPD NERP energy useage by fuel type
Annually
GJ
NOx Factors by fuel type
Annually
Kg/tonne
Crude oil and other hydrocarbons import (i.e. feedstocks)
Annually
Tonnes
Water usage
Annually
Tonnes
Energy usage (electrical)
Annually
MWh
Energy usage (all fuels)
Annually
MJ
Total release of oil to water per tonne of feedstock
Annually
g oil / 1000 tonnes feedstock
Page 25
Table S5.4 Reporting forms
Media/parameter
Reporting format
Air – LCPD
SO2, NOx, Dust
Form Air – 1 Discontinuous monitoring or other form as agreed in
writing by the Agency
Air – LCPD
SO2, NOx, Dust
Form Air – 2 continuous monitoring or other form as agreed in writing
by the Agency
01/01/08
Air – LCPD
SO2, NOx, Dust
Form Air – 3 continuous measurement systems invalidation log or
other form as agreed in writing by the Agency
01/01/08
Air – LCPD
Form Air – RTA 1 NERP LCP mass reporting or other form as agreed
in writing by the Agency
01/01/08
Air - LCPD
Form Energy – AAE 1 NERP LCP annual energy useage
01/01/08
Air – LCPD
Fuels used
Form Air – 4 Annual fuels used (in GJ, ncv basis) and mass release
report for SO2, NOx, Dust for each LCP over 4 quarters to annual
mass release report in accordance with Annex VIIIB of the LCPD
01/01/08
Air – Fuels, Sulphur Balance,
SRU performance
Form Air – 5 Refinery fuel analyses (daily average data – RFO, RFG),
Refinery Sulphur Balance and SRU availability and efficiency
01/01/08
Air – FCCU
SO2, NOx, CO, Dust
Form Air – 6 continuous monitoring or other form as agreed in writing
by the Agency
01/01/08
Air - Flares
Form Air – 7 Report of the flaring rate and energy loss and SO2
released from flaring.
01/01/08
Air - VOCs
Form Air – 8 Report of VOC losses [following the Institute of
Petroleum protocol]
01/01/08
Air – VOCs
Form Air – 9 PRV VOC releases
01/01/08
Air - NOx Factors
Form Air - 10 NOx factor annual review
01/01/08
Air – SO2 ELVs
Form Air – 11 SO2 Hourly Stack ELVs and Refinery Bubble
01/01/08
Water
Form Water – 1 Daily. Flow, oil, pH, temperature and TOC
01/01/08
Water
Form Water – 2 Weekly. COD, Ammoniacal Nitrogen, phenols,
sulphide, Fluoride and suspended solids.
01/01/08
Water
Form Water – 3 Quarterly Cyanide and Heavy Metals
01/01/08
Water usage
Form Water Usage1 or other form as agreed in writing by the Agency
01/01/08
Energy usage
Form Energy 1 or other form as agreed in writing by the Agency
01/01/08
Waste
Form Waste1 or other form as agreed in writing by the Agency
01/01/08
Other performance indicators
Form Performance 1 or other form as agreed in writing by the Agency
Tables S5.2 and S5.3 indicators.
01/01/08
Page 26
Date of form
01/01/08
Schedule 6 - Notification
These pages outline the information that the operator must provide.
Units of measurement used in information supplied under Part A and B requirements shall be appropriate
to the circumstances of the emission. Where appropriate, a comparison should be made of actual
emissions and authorised emission limits.
If any information is considered commercially confidential, it should be separated from non-confidential
information, supplied on a separate sheet and accompanied by an application for commercial
confidentiality under the provisions of the PPC Regulations.
Part A
Permit Number
Name of operator
Location of Installation
Time and date of the detection
(a) Notification requirements for any malfunction, breakdown or failure of equipment or techniques,
accident, or fugitive emission which has caused, is causing or may cause significant pollution
To be notified within 24 hours of detection
Date and time of the event
Reference or description of the
location of the event
Description of where any release
into the environment took place
Substances(s) potentially
released
Best estimate of the quantity or
rate of release of substances
Measures taken, or intended to
be taken, to stop any emission
Description of the failure or
accident.
(b) Notification requirements for the breach of a limit
To be notified within 24 hours of detection unless otherwise specified below
Emission point reference/ source
Parameter(s)
Limit
Measured value and uncertainty
Date and time of monitoring
Measures taken, or intended to
be taken, to stop the emission
Page 27
Time periods for notification following detection of a breach of a limit
Parameter
Notification period
(c) Notification requirements for the detection of any significant adverse environmental effect
To be notified within 24 hours of detection
Description of where the effect on
the environment was detected
Substances(s) detected
Concentrations of substances
detected
Date of monitoring/sampling
Part B - to be submitted as soon as practicable
Any more accurate information on the matters for
notification under Part A.
Measures taken, or intended to be taken, to
prevent a recurrence of the incident
Measures taken, or intended to be taken, to rectify,
limit or prevent any pollution of the environment
which has been or may be caused by the emission
The dates of any unauthorised emissions from the
installation in the preceding 24 months.
Name*
Post
Signature
Date
* authorised to sign on behalf of ConocoPhillips Ltd
Page 28
Schedule 7 - Interpretation
"accident" means an accident that may result in pollution.
"annually" means once every year.
“application” means the application for this permit, together with any additional information supplied by
the operator as part of the application and any response to a notice served under Schedule 4 to the PPC
Regulations.
“assessment year” means the 15 month period up to 31 March each year for NERP assessment and
allocation transfer resolution.
“authorised officer” means any person authorised by the Agency under section 108(1) of The
Environment Act 1995 to exercise, in accordance with the terms of any such authorisation, any power
specified in section 108(4) of that Act.
“Sector Guidance Note” means IPPC Sector Guidance Note on Gasification, Liquefaction and Refining
Activities, IPPC S1.02.
“CEM” means continuous emission monitor.
“CEN” means Commité Europeén de Normalisation.
“Class A VOCs” means as referenced in TGN M16 pg 5.
“DSD” means Dangerous Substances Directive.
“emissions to land”, includes emissions to groundwater.
“FCCU” means fluidised catalytic cracking unit.
“fugitive emission” means an emission to air, water or land from the activities which is not controlled by
an emission limit.
“groundwater” means all water, which is below the surface of the ground in the saturation zone and in
direct contact with the ground or subsoil.
“ISO” means International Standards Organisation.
“land protection guidance”, means Agency guidance "H7 - Guidance on the protection of land under the
PPC Regime: application site report and site protection monitoring programme".
“large combustion plant” or “LCP” is a combustion plant or group of combustion plants discharging waste
gases through a common windshield or stack, where the total thermal input is 50 MWth or more, based
on gross calorific value.
“Large Combustion Plant Directive” means Directive 2001/80/EC of the European Parliament and of the
Council of 23 October 2001 on the limitation of emissions of certain pollutants into the air from large
combustion plants.
“LCP plant closure” means when the rated capacity of a LCP falls below 50 MWth
Page 29
“ Invalid hourly average” means an hourly average period invalidated due to malfunction of, or
maintenance work being carried out on, the continuous measurement system. However, to allow some
discretion for zero and span gas checking, or cleaning (by flushing), an hourly average period will count
as valid as long as data has been accumulated for at least two thirds of the period (40 minutes). Such
discretionary periods are not to exceed more than 5 in any one 24-hour period unless agreed in writing.
Where plant may be operating for less than the 24-hour period, such discretionary periods are not to
exceed more than one quarter of the overall valid hourly average periods unless agreed in writing.
“invalid day” means any day in which more than three hourly average values are invalid.
“LDAR”, means Leak Detection and Repair, a managed scheme and programme for testing potential
sources of fugitive emissions, from operational plant at the installation, and repairing or carrying out other
actions to prevent, or where that is not possible, minimise continued emissions from those sources. The
LDAR programme at the installation shall be consistent with the requirements of the API Protocol.
“MCERTS” means the Environment Agency’s Monitoring Certification Scheme.
“METH” means the Operator in house laboratory method reference that is in general accordance with the
national/international standard quoted along with that standard.
“National Emission Reduction Plan” (NERP) is the plan issued by Defra in accordance with Article 4.6 of
the Large Combustion Plants Directive and associated guidance
“Natural gas” means naturally occurring methane with no more than 20% by volume of inert or other
constituents
“NERP Register “ means the register maintained by the Environment Agency in accordance with
regulation 6(1) of the Large Combustion Plants (National Emission Reduction Plan) Regulations 2007.
“ncv” means net calorific value.
“notify without delay” and “notified without delay” means that a telephone call can be used, whereas all
other reports and notifications must be supplied in writing, either electronically or on paper.
“PPC Regulations” means the Pollution, Prevention and Control (England and Wales) Regulations SI
2000 No.1973 and words and expressions used in this permit which are also used in the Regulations
have the same meanings as in those Regulations.
"quarter" means a calendar year quarter commencing on 1 January, 1 April, 1 July or 1 October.
“site protection and monitoring programme” means a document which meets the requirements for site
protection and monitoring programmes described in the Land Protection Guidance.
“SRU” means sulphur recovery unit.
“SRU performance evaluation” means measurement of process stream compositions, overall and interstage material balances, calculation of overall and inter-stage recovery efficiency, performance check of
key equipment items [reaction furnaces, condensers, reheaters, converters (including superclaus),
incinerator], key analyser performance checks and recommendations for unit performance improvements
[including how to restore recovery to design capability]
Page 30
“ hourly bubble” means the average release concentration for the release points included within the
bubble over a discrete one hour period.
“t/h equivalent” means for periods of flaring the total release in tonnes over any hour.
“Waste code” means the six digit code referable to a type of waste in accordance with the List of Wastes
(England)Regulations 2005, or List of Wastes (Wales) Regulations 2005, as appropriate, and in relation
to hazardous waste, includes the asterisk.
“year” means calendar year ending 31 December.
Where a minimum limit is set for any emission parameter, for example pH, reference to exceeding the
limit shall mean that the parameter shall not be less than that limit.
Unless otherwise stated, any references in this permit to concentrations of substances in emissions into
air means:
(a) in relation to emissions from combustion processes, the concentration in dry air at a temperature of
273K, at a pressure of 101.3 kPa and with an oxygen content of 3% dry for liquid and gaseous fuels,
6% dry for solid fuels; and/or
(b) in relation to emissions from gas turbine and compression ignition engine combustion processes, the
concentration in dry air at a temperature of 273K, at a pressure of 101.3 kPa and with an oxygen
content of 15% dry for liquid and gaseous fuels; and/or
(c) in relation to emissions from non-combustion sources, the concentration at a temperature of 273K
and at a pressure of 101.3 kPa, with no correction for water vapour content
END OF PERMIT
Page 31

basic materials and example of ippc permit

Transcription

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