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CURRENT AND FUTURE STANDARDS & GUIDELINES FOR OIL & GAS SECTOR IN
INDIA AND STATUS OF ITS IMPLEMENTATION
Presented at International Conference on “Occupational and Environmental Health”
Organised by Oil Industry Safety Directorate in collaboration with Drexel University,
School of Public Health, Philadelphia, USA held during December 13-14 , 2013
DR. B. SENGUPTAMember EAC (Industry) - MoEF
Former Member SecretaryCentral Pollution Control Board
Email: [email protected]
1. The Water (Prevention & Control of Pollution) Act, 1974
2. The Water (Prevention & Control of Pollution) Cess, Act, 1977
3. The Air (Prevention & Control of Pollution) Act, 1981
4. The Environment (Protection) Act, 1986
5. The Hazardous Waste (Management and Handling) Rules 1989, 2003, 2009
6. The Bio - Medical Waste (Management and Handling) Rules 1988, 2003
7. The Municipal Solid Wastes (Management and Handling) Rules 2000
8. The Plastics Manufacture and Usage Rules, 1999
9. The Noise Pollution (Regulation & Control) Rules, 2000
10. The Batteries (Management and Handling) Rules, 2001
11. Environmental Impact Assessment Notification, 2006, 2009
12. National Environmental Policy, 2006
13. Fly Ash Management Rule, 2008
14. Ambient Air quality standard , 1982, 1995, 2009
15. Proposed national environmental assessment and monitoring authority, 2010
MAJOR ENVIRONMENTAL ACTS/RULES/POLICY
PRESENT SCENARIO
� Present indigenous crude oil production is30 million tones per annum (ONGC, RIL,Carin Energy, Oil India) etc.
� Present import of crude oil is about 100million tones per annum
� Growth in oil consumption (astransportation fuel, industry and domesticfuel) is about 7.8%.
RECENT DEVELOPMENTS IN THE FIELD OF POLLUTION
CONTROL RELEVANT FOR OIL INDUSTRY SECTOR:-
� Amendment in EIA 2006 notification in 2009.
� Amendment in hazardous waste management rule 1989 in 2009.
� Notification of new ambient air quality standard 2009.
� Declaration of 43 critically polluted areas (CPA) based on
comprehensive environmental pollution index (CEPI) and restriction
of new industries and its expansion of existing industry in CPA.
� Revision of oil refineries standard and notification under EPA act.
GSR 186(E) 18 March 2008.
� Enforcement of Bharat stage III and Bharat stage IV fuel quality in
2010.
� Post-project monitoring guidelines 2010 for post project monitoring
� CREP recommendation implementation
STANDARD AND GUIDELINES FOR OIL DRILLING & GAS EXTRACTION SECTOR
AIR POLLUTION CONTROL FROM OIL DRILLING
AND GAS EXTRACTION INDUSTRY
� The Air (Prevention and Control of Pollution) Act, 1981and amendments thereafter.
� The Environment Protection Act, 1986 – Guidelines fordischarge for gaseous emissions by Oil Drilling andGas Extraction Industry as notified vide notificationdated GSR 176(E) April, 1996
� The Environment (Protection) Second AmendmentRules, 2002 Emission Standards for New GeneratorSets.
� The Factories Act, 1948 and amendments thereafter.
� The Motor Vehicle Act, 1938 and amendmentsthereafter.
AMBIENT AIR QUALITY STANDARDS 2009
S.No. Pollutant Time Weighted Average
Concentration in Ambient Air
Methods of Measurement
Remarks
Industrial, Residential, Rural and Other Area
Ecologically Sensitive Area (notified by Central Government)
(1) (2) (3) (4) (5) (6) (7)
1. Sulphur Dioxide (SO2), µg/m3
Annual*24 hours**
5080
2080
a) Improved West and Gaekeb) Ultraviolet fluorescence
Facilities available
2. Nitrogen Dioxide (NO2), µg/m3
Annual*24 hours**
4080
3080
a) Modified Jacob & Hocheiser (Na-Arsenite)b) Chemiluminiscence
Facilities available
Contd..
3. Particulate
Matter
(size less
than 10
µm) or
PM10 µg/m3
Annual*
24 hours**
60
100
60
100
a)
Gravimetric
b) TOEM
c) Beta
attenuation
• Most of the NAMP Stations
have Gravimetric
measurement facility
including CPCB
• CAQMS is having BAM
• TEOM has to be introduced
gradually
4. Particulate
Matter
(size less
than 2.5
µm) or
PM2.5 µg/m3
Annual*
24 hours**
40
60
40
60
a)
Gravimetric
b) TOEM
c) Beta
attenuation
• Gravimetric measurement
facility may be developed
countrywide
• CAQMS is having BAM
• TEOM is yet to be
introduced gradually
5. Ozone (O3)
µg/m3
8 hours*
1 hour**
100
180
100
180
a) UV
photometric
b)
Chemilumini
scence
c) Chemical
Method
• CAQMS equipped with UV
based or
Chemiluminescence Online
Analysers and may be used
for 1 hrly data
• Chemical method may be
adopted nationwide but
monitoring hours is not
specified, however 09 hrs to
17 hrs may be introduced
Contd..
6. Lead (Pb) µg/m3
Annual*24hours**
0.51.0
0.51.0
a) AAS/ICP method after sampling on EPM 2000 or equivalent filter paper
b) ED-XRF using Teflon filter
• It appears that Pb is to be monitored in PM10, this standard already exists but monitored in SPM only at few locations.
• Once the sampling is done in Teflon the same may also be analyzed by other method ED-XRF
7. Carbon Monoxide (CO) µg/m3
8 hours*1 hour**
0204
0204
Non Dispersiv Infra Red (NDIR) spectroscopy
• Only option is to go with online analyzer
8. Ammonia (NH3) µg/m3
Annual*24hours**
100400
100400
a)Chemiluminiscenceb) Indophenol blue
method
• Recently introduced at few locations in CAQMS
• Chemical method may be adopted nationwide
9. Benzene (C6H6) µg/m3
Annual* 05 05 a)Gas chromatography based continuous analyzer
b) Adsorption and Desorption followed by GC analysis
• BTX analysers are being used at CAQMS
• Active 24 hourly sampling in diffusion tubes followed by desorption in CS2 and finally GC Analysis may be adopted nationwide in NAMP Contd..
10. Benzo(a)
Pyrene
(BaP) –
particulat
e phase
only,
ng/m3
Annual* 01 01 Solvent
extraction
followed by
HPLC/GC
analysis
• Facilities available with
CPCB but BIS method using
GC-FID may not attain the
desired lowest concentration
level below 1ng/m3
alternatively GC-MS or
HPLC-UV Fluorescence may
be provided
11. Arsenic
(As),
ng/m3
Annual* 06 06 AAS/ICP
method after
sampling on
EPM 2000 or
equivalent
filter paper
• It appears that ‘As’ is to be
monitored in PM10.
• Micro-wave digester is
required for digestion
alternatively acid digestion
at 700 C for 12 hours is
required.
12. Nickel
(Ni),
ng/m3
Annual* 20 20 AAS/ICP
method after
sampling on
EPM 2000 or
equivalent
filter paper
• It appears that ‘Ni’ is to be
monitored in PM10.
• Micro-wave digester is
required for digestion
alternatively acid digestion
at 700 C for 12 hours is
required.
WATER POLLUTION CONTROL FROM OIL DRILLING AND GAS EXTRACTION INDUSTRY
� The Water (Prevention and Control ofPollution) Act, 1974 and amendmentsthereafter.
� The Environment Protection Act, 1986 –Standards for liquid discharge by OilDrilling and Gas Extraction Industry asnotified vide notification dated GSR 176(E) April, 1996.
SOLID / HAZARDOUS WASTES FROM OIL DRILLING AND GAS EXTRACTION INDUSTRY
� Hazardous Wastes (Management, Handling andTrans-boundary Movement) Rules, 2008 andamendments thereafter
� Guidelines for disposal of solid waste by OilDrilling and Gas Extraction industry as notified,vide notification dated GSR 176 (E) April, 1996.
� Manufacture Storage and Import of HazardousChemicals 1989 and amendments thereafter.
OIL SPILL MANAGEMENT
� Oil spillage management scheme to beprepared.
� In case of oil spillage/contamination,action plan to be prepared to clean thesite by adopting proven technology.
� The recyclable waste (oily sludge) andspent oil to be disposed off to theauthorized recyclers/reprocessors.
H2S RELEASE FROM OIL DRILLING AND GAS EXTRACTION INDUSTRY
� A contingency plan for H2S release to bein place.
� Evacuation to resumption of normaloperations.
� Workers to be provided with personal H2Sdetectors in locations of high risk ofexposure alongwith self containingbreathing apparatus.
SOLID WASTE, DRILL CUTTING AND DRILLING FLUIDS MANAGEMENT
� Solid waste, drill cutting and drilling fluidsdisposal for onshore drilling operation as pervide GSR. 546(E) dated 30th August, 2005.
� Drill cutting (DC) wash water to be treated toconform to limits notified under theEnvironment (Protection) Act, 1986 beforedisposal.
� The treated effluent shall be monitoredregularly.
� Top soil removed to be stacked separately forreuse during restoration process.
RESTORATION OF DRILLING SITE
� Measures after completion of drilling process :
- Well plugging and secured enclosures,- decommissioning of rig upon abandonment of
the well and,- restoration of the drilling site to the original
condition.
� If no economic quantity of hydrocarbon is found :
- A full abandonment plan to be implemented forthe drilling site as per Indian PetroleumRegulations.
STANDARDS AND GUIDELINES FOR OIL DRILLING AND GAS EXTRACTION SECTOR
� Water based mud system for drilling only to be used.
� Diesel based mud use for drilling to be eliminated.
� Mud decant water to be recycled.
� Drill cuttings (DC) originating from onshore or location closed
to shore line and separated from water based mud (WBM)
should be properly washed and unusable drilling fluids (DF)
should be disposed off in a well designed pit lined with
impervious liner located off-site or on-site.
� The disposal pit should be provided with leachate collection
system
� Design aspects of the impervious waste disposal pit, capping
of the disposal pit should be informed to SPCB at the time of
obtaining consent.
� Incase of any problem due to geological formation for
drilling, low toxicity OBM having aromatic content less
than 1% should be used.
� The chemical additives used for the preparation of DF
should have low toxicity that is 96 hrs LC50 more than
30,000 mg/l as per toxicity test conducted on locally
available sensitive sea species. The chemical used
should be biodegradable.
� DC separated from OBM after washing should have oil
content at less than 10 mg/kg for disposal into disposal
pits.
� Hydrogen sulphide scavengers to prevent
degradation of sweet wells by sulphate reducing
bacteria to be used.
� Select less toxic biocides corrosion inhibitors
and other chemicals.
� Minimize gas flaring.
� Store crude oil in tanks having secondary double
seal.
� Minimize and control leakage from tanks and
pipelines.
� Proactive corrosion prevention and monitor above and below
ground tanks, vessels, pipes etc.
� Remove hydrogen sulphide and mercaptans from soar gases
before flaring.
� Use knock out drums on flares to prevent condensate
emission.
� Regenerate spent amines and spent solvents or send off site
for recovery.
� Provide spill prevention and control measures (bunds, berms
and hard surfacing for storage tanks, pressure relieve valves,
high level alarms)
� Recover oil from process waste water.
� Segregate storm water from process water.
� Implement leak detection and repair programmes.
STANDARD AND GUIDELINES FOR OIL REFINERY SECTOR
LEGAL REQUIREMENT FOR POLLUTION CONTROL - OIL REFINERY
� To obtain Consent under Water Act, 1974.
� Payment of water cess as per Water Cess Act, 1977.
� To obtain Consent under Air Act, 1981.
� To obtain Authorization for hazardous waste
management under Hazardous Waste Management
Rules, 1989.
� To obtain EC under EIA 2006 for new setting-up new
refinery / expansion of existing refinery.
� Submission of environmental statement (Audit) report.
� Submission of EC compliance report and also posting of
the same on industry website.
Fuel Type Existing
refineries
New Refinery/
Furnace / Boiler
Sulphur Dioxide
(SO2)
Gas 50 50
Liquid 1700 850
Oxides of Nitrogen
(NOx)
Gas 350 250
Liquid 450 350
Particulate Matter
(PM)
Gas 10 5
Liquid 100 50
Carbon Monoxide
(CO)
Gas 150 100
Liquid 200 150
Nickel and Vanadium
(Ni+v)
Liquid 5 5
Hydrogen Sulphide (H2S)
in fuel gas
Liquid / Gas 150 150
Sulphur content in liquid
fuel, weight%
Liquid / Gas 1.0 0.5
EMISSION STANDARDFURNACE / BOILER / CAPTIVE POWER PLANT
Limiting concentration in mg/Nm3, unless stated
Note : No solid fuel (coal / petcoke etc.) in captive power plant
??
Notes:-
(i) In case of mixed fuel (gas and liquid) use, the limit shall be computed
based on heat supplied by gas and liquid fuels.
(ii) All the furnaces/boilers with heat input of 10 million kilo calories/hour or
more shall have continuous systems for monitoring of SO2 and NO2.
Manual monitoring for all the emission parameters in such furnaces or
boilers shall be carried out once in two months.
(iii) All the emission parameters in furnaces/boilers having heat input less
than 10 million kilo calories/hour will be monitored once in three months.
(iv) In case of continuous monitoring, one hourly average concentration
values shall be complied with 98% of the time in a month. Any
concentration value obtained through manual monitoring, if exceeds the
limiting concentration value, shall be considered as non-compliance.
(v) Data on Nickel and Vanadium content in the liquid fuel (in ppm) shall be
reported. Nickel and Vanadium in the liquid fuel shall be monitored at
least once in six months, if liquid fuel source & quality are not changed. In
case of changes, measurement is necessary after every change.
EMISSION STANDARDFURNACE / BOILER / CAPTIVE POWER PLANT
Existing refineries New Refinery
/FCC
CommissionedHydro
processed
Other than
Hydro
Sulphur Dioxide (SO2) 500 1700 500 (for hydro-
processed feed)
850 for other
feed)
Oxides of Nitrogen (NOx) 400 450 350
Particulate Matter (PM) 100 100 50
Carbon Monoxide
(CO)
400 400 300
Nickel and Vanadium (Ni+V) 2 5 2
Opacity, % 30 30 30
EMISSION STANDARD FCC REGENERATORS
Limiting concentration in mg/Nm3, unless stated
Note : Opacity meter to be installed in FCC regenerator stack.
Notes:-
(i) In case part feed is hydro-processed, the emission values shall becalculated proportional to the feed rates of untreated and treatedfeeds.
(ii) FCC regenerators shall have continuous systems for monitoring ofSO2 and NOx. One hourly average concentration values shall becomplied with 98% of the time in a month, in case of continuousmonitoring. Manual monitoring for all the emission parameters shallbe carried out once in two months.
(iii) Any concentration value obtained through manual monitoring, ifexceeds the limiting concentration value, shall be considered asnon-compliance.
(iv) Data on Sulphur (weight in %), Nickel (PPM) and Vanadium (PPM)content in the feed to FCC shall be separated regularly.
(v) Limit of Carbon Monoxide emissions shall be complied with exceptduring annual shut down of CO boiler for statutory maintenance.
EMISSION STANDARD FCC REGENERATORS
EMISSION STANDARD SULPHUR RECOVERY UNITS
Plant
Capacity
(Tonnes/day)
Existing
SRU
New SRU or
Refinery
Commissioned
Sulphur recovery, % Above 20 98.7 99.5
H2S, mg/Nm3 - 15 10
Sulphur recovery, % 5-20 96 98
Sulphur recovery, % 1-5 94 96
Oxides of Nitrogen
(NOx), mg/Nm3
All capacity 350 250
Carbon Monoxide All capacity 150 100
Note : NOx, CO, H2S monitoring system to be installed.
Notes:-
(i) Sulphur recovery units having capacity above 20 tonnes perday shall have continuous systems for monitoring of SO2.Manual monitoring for all the emission parameters shall becarried out once in a month.
(ii) Data on Sulphur Dioxide emissions (mg/Nm3) shall bereported regularly.
(iii) Sulphur recovery efficiency shall be calculated on monthlybasis, using quantity of sulphur in the feed to SRU andquantity of sulphur recovered.
EMISSION STANDARD SULPHUR RECOVERY UNITS
STANDARDS FOR EQUIPMENT LEAKS LDAR PROGRAMME
(1) Approach for controlling fugitive emissions from equipment
leaks shall have proper selection, installation and maintenance
of non-leaking or leak-tight equipment. Following initial
testing after commissioning, the monitoring for leak detection is
to be carried out as a permanent on-going Leak Detection and
Repair (LDAR) programme. Finally detected leaks are to be
repaired within allowable time frame.
(2) Components to be Covered: Components that shall be covered
under LDAR programme include (i) Block valves; (ii)
Control valves; (iii) Pump seals; (iv) Compressor seals; (v)
Pressure relief valves; (vi) Flanges- Heat Exchangers; (vii)
Flanges - Piping; (viii) Connectors - Piping; (ix) Open ended
lines; and (x) Sampling connections, Equipment and line sizes
more than 1.875 cm or ¾ inch are to be covered.
(3) Applicability: LDAR programme would be applicable to
components (given at 2 above) for following products /
compounds: (i) hydrocarbon gases; (ii) Light liquid with
vapour pressure @ 20o C > 1.0 kPa; and (iii) Heavy
liquid with vapour pressure @ 20o C between 0.3 to 1.0 kPa.
(4) WHILE LDAR will not be applicable for heavy liquids with
vapour pressure < 0.3 kPa, it will be desirable to check for
liquid dripping as indication of leak.
(5) Definition of leak: A leak is defined as the detection of VOC
concentration more than the values (in ppm) specified below
at the emission source using a hydrocarbon analyzer
according to measurement protocol (US EPA - 453/R-95-
017, 1995 Protocol for equipment leak emission estimates
may be referred to:
STANDARDS FOR EQUIPMENT LEAKS LDAR PROGRAMME
Component General Hydrocarbon
(ppm)
Benzene (ppm)
Till 31st
Dec. 2008
w.e.f.
January 01,
2009
Till 31st
Dec., 2008
w.e.f January
01, 2009
Pump/Compressor 10000 5000 3000 2000
Valves/Flanges 10000 3000 2000 1000
Other components 10000 3000 2000 1000
(6) In addition, any component observe to be leaking by sight, sound or
smell, regardless of concentration (liquid dripping, visible vapor leak) or
presence of bubbles using soap solution should be considered as
leak.
(7) Monitoring Requirements and Repair Schedule: Following frequency of
monitoring of leaks and schedule for repair of leaks shall be followed:
STANDARDS FOR EQUIPMENT LEAKS LDAR PROGRAMME
Component Frequency of monitoring Repair schedule
Quarterly (semiannual after two
consecutive periods with < 2% leaks and
annual after 5 periods with < 2% leaks)
Repair will be
started within 5
working days
and shall be
completed
within 15
working days
after detection
of leak for
general
hydrocarbons. In
case of benzene,
the leak shall be
attended
immediately for
repair.
Pump seals Quarterly
Compressor seals Quarterly
Pressure relief devices Quarterly
Pressure relief devices
(after venting)
Within 24 hours
Heat Exchangers Quarterly
Process drains Annually
Components that are
difficult to monitor
Annually
STANDARDS FOR EQUIPMENT LEAKS LDAR PROGRAMME
Pump seals with visible
liquid dripping
Immediately Immediately
Any component with
visible leaks
Immediately Immediately
Any component after
repair/ replacement
Within five days -
STANDARDS FOR EQUIPMENT LEAKS LDAR PROGRAMME
EMISSION STANDARDS FOR VOC / ODOUR FROM WASTEWATER COLLECTION AND TREATMENT
(1) All contaminated and odorous wastewater streams shall be handled inclosed systems from the source to the primary treatment stages (oil-water separator and equalization tanks).
(2) The collection system shall be covered with water seals (traps) onsewers and drains and gas tight covers on junction boxes.
(3) Oil-water separators and equalization tanks shall be providedwith floating/fixed covers. The off-gas generated shall be treated toremove at least 90% of VOC and eliminate odour. The system designshall ensure safety (prevention of formation of explosive mixture,possible detonation and reduce the impact) by dilution with air/inertgas, installing LEL detector including control devices, seal drums,detonation arrestors etc. The system shall be designed and operatedfor safe maintenance of the collection and primary treatment systems.
(4) Wastewater from aromatics plants (benzene and xylene plants) shallbe treated to remove benzene & total aromatics to a level of 10, 20ppm respectively before discharge to effluent treatment system withoutdilution].
EFFLUENT STANDARD
1. pH 6.0-8.5
2. Oil & Grease 5.0
3. BOD 3 days, 27oC 15.0
4. COD 125.0
5. Suspended Solids 20.0
6. Phenols 0.35
7. Sulphides 0.5
8. CN 0.20
9. Ammonia as N 15.0
10. TKN 40.0
11. P 3.0Unit : mg/l except pH
12. Cr (Hexavalent) 0.1
13. Cr (Total) 2.0
14. Pb 0.1
15. Hg 0.01
16. Zn 5.0
17. Ni 1.0
18. Cu 1.0
19. V 0.2
20. Benzene 0.1
21. Benzo (a) - Pyrene 0.2
EFFLUENT STANDARD
Unit : mg/l
EC CONDITION COMPLIANCE FOR
OIL REFINERY
PETROLEUM OIL REFINERY AND PETROCHEMICALS
FUEL QUALITY STANDARDS
1 % in NCT &
Mumbai
Feb
2000
Unleded
Country
5 %
April 1996
April 2000
3% in Metro cities
Nov. 2000 3 % in all India
&
1% in Major Metros
April. 2005
3 % in all India
April. 2010
June
1994
0.15 g/l
(4 metro)
April
1995
Unleaded
4 metros
Low leaded
Entire Country
Jan
1997
Jan
1999
Unleaded
NCR
Gasoline Benzene Reduction Programme
in India
Gasoline Lead Phase-out Programme In India
Before 1996
No Specifications
Vehicle Emission Norm Schedule In India
1990
1st set norms
notified
1995
Emission norms for
catalytic vehicles
1996
2nd set norms
notified
2000/01
Euro-I equivalent (Country)
Euro-II eqv. For cars (4 metros)
2005
Euro-II (Country)
Euro-III (11 cities)
2010
Euro-III (Country)
Euro-IV (11 cities)
August 1997
Sulphur 0.25%
Delhi & Taj
Sulphur 0.25%
Metro cities
April 1998
Sulphur 0.25%
Entire Country
April-2000
April 2000-04
Sulphur 0.05%
11 cities
April
April6
Sulphur 0.50 %
4 metros & Taj
Diesel Sulphur Reduction Programme
Sulphur 0.05%
Entire Country
& 0.035 (11 cities)
April-2005
April-2010
Sulphur 0.005% (11 cities)
& 0.035%
(Entire Country)
FINDINGS OF CPCB SOURCE APPORTIONMENT STUDY
1) Levels of PM10 and PM2.5 in the ambient air were found to besignificantly high irrespective of locations. The concentration of thesepollutants are relatively higher at kerbside locations. Vehicles contributeto PM10 & PM2.5 at all locations, but their contribution to kerbsidelocations was relatively higher. At Kanpur and Delhi, almost at alllocations and in all standards of PM10 and PM2.5 are exceeded.
2) Winter and post-monsoon seasons were found to be most critical whenstandard exceedence rates are higher than in summer months.
3) PM pollution problem is severe in the six cities and NOx was found to bean emerging pollutant.
4) With respect to air toxics, Benzene levels were found to be higher inBangalore, Pune and Kanpur. Formaldehyde marginally exceedpermissible limits in Mumbai, Pune and Bangalore.
5) High Elemental Carbon (EC) to Organic Carbon (OC) ration (EC/OC)represents freshly contributed diesel/coal/biomass/garbage combustionparticles (OC being contributed mainly from secondary organic aerosolformation). This ratio was found to be high for most cities.
6) Significant quantities of sulfates and nitrates were found in PM10indicating an important contribution of secondary particles.
7) Presence of molecular markers like hopanes and steranes in muchhigher quantities indicate contribution from vehicles. Higherconcentration from levoglucosan indicates biomass burning.
8) Within the transport sector, the PM10 contribution in terms ofemission load is mainly from heavy duty diesel vehicles (40-59%) inalmost all the cities. Also, they are also the important contributors ofNOx (43-75%).
9) Though there are city-specific variations among the dominance ofsources, re-suspension of road dust and combustion sources(including vehicles, refuse burning and DG sets) are prominentsources of PM in all cities.
10) Morning and evening peaks in CO levels corresponding to vehicularmovement.
FINDINGS OF CPCB SOURCE APPORTIONMENT STUDY
RECOMMENDATION (AS SUBMITTED BY SUBGROUP I AND II) TO IMPROVE AIR QUALITY TO MAIN COMMITTEE ON AUTO FUEL VISION
AND POLICY 2025
1. Road map for fuel quality improvement:
– Since the year 2000, differential norms are implemented in metros andrest of the country due to non-availability of uniform quality fuel acrossthe country. Due to non-availability of appropriate quality fuel, thevehicles of advance technology registered in metros and major citiesare deteriorating fast, defeating the purpose.
– Ensuring nationwide same quality of fuel will reduce emissions of in-use vehicle pollution noticeably due to the fact that the after-treatmentdevices and other newer technologies are very susceptible to thequality of fuel used. Very short distance exposure to low grade fuelquality may deteriorate these devices and thus make newergenerations of in-use vehicles not effective or worse than those ofearlier generation vehicles due to the deterioration of emission controldevices. With this background, it is desirable to have the policy of “OneCountry-One Fuel-One Norm”.
– Learning from the experience due to dual fuel policy, “One-CountryOne-Fuel One-Norm” policy implementations to optimize resourcesand maximize the benefits is proposed. In view of this, by 2016 orearlier country should have “One Fuel” i.e. BS-IV Gasoline with50ppm Sulfur and 91 Octane. However, premium fuel with 95 RONshould also be available in the areas where such fuel compliantvehicles are populated.
– In view of large consumption of HSD in off road applications, thereis a need to look into the feasibility of having two grades of dieselfuels in the country [off-road and on-road applications].
– India is consuming more of diesel fuel compared to gasoline andhence there is need to maximise production of diesel fuel. In thelight of this, studies should be undertaken to see the impact ofincreasing T95 of diesel from existing 360degC to 370degC and incase no significant influence is observed then T95 of HSD as370degC may be adopted, which is likely to improve the availabilityof diesel fuel in the country.
– In order to conserve fuel and improve ambient air quality in thecountry, fuel additives with proven credentials must be promoted.The additised fuels which help the fuel efficiency and emissionreduction should attract less duty.
2. Recommendations of AFP-2003 which are yet to be
implemented should be considered as a starting point for
AFV&P-2025.
3. Consumer education on eco-friendly driving habits to curb
pollution and improve fuel economy should be encouraged.
4. AFV&P-2025 shall promote use of appropriate multi-modal
transport such as Bus Rapid Transit (BRT) and other Mass
Transport Systems. JNNURM to predict multi-modal transport
system considering current & future demographics.
5. AFV&P-2025 shall ensure quality infrastructure and address
the following issues for sustainable transportation & auto
industry growth -
– Inspection & Maintenance regime across the country
– In future, ITS enablement & End of Life (old vehicle scrapping policyincluding fiscal incentives) vehicle management to be enforced
– Urban & Rural Infrastructure & Road network quality
– Traffic management (parking on-street & off-street, bus stops, roadinformation systems, training & education)
– Urban & rural transport planning in conjunction with land usedevelopment plan
– Pedestrian facilities e.g. subway, foot over-bridge/ under-bridge,footpath etc. to streamline the traffic flow & reduce accident therebyimproving overall road safety.
6. As PM10 and PM2.5 concentrations in 83 cities / towns have
reached at critical level (100% to 450% times the notified
ambient air quality standard), immediate attention is required
to prepare an action plan to reduce fine particulate pollution.
The integrated action plan to be prepared, keeping the
ultimate objective to meet PM2.5 standard in ambient air,
which must include the following:
– Diesel particulate filter (DPF) installation in existing old diesel vehicles
(buses, trucks and commercial vehicles).
– Supply of BSIV fuel in these polluted cities at the earliest.
– Improved I/M programme for control of emission from in-use vehicles.
– Supply of clean transportation fuel (CNG/LPG) in all cities where it is possible
to supply CNG / LPG particularly for 3-wheelers.
– Restriction on use of highly polluting DG Sets.
– Controlling particulate emissions from power plant/SSI units effectively.
– Indentifying grossly polluting in-use vehicles and phasing them out.
7. For all non-attainment cities, and critically polluted areas,action plans need to be prepared. The action plans shouldinclude emission inventories, air quality monitoring, air qualitymodelling, source apportionment studies, etc. Once prepared,the action plans should be implemented by correspondingstate authorities and overseen by a high powered expertcommittee.
8. Air toxics (Benzene, 1,3 butadiene, aldehydes, polycyclicaromatic hydrocarbon, metals, etc) assessment, monitoringand control should be given the highest priority. The limitedmeasurement done by CPCB show significantly high valuesof air toxics in ambient air. MoEF may setup an expert body toinitiate the work on air toxic management.
9. Action plans prepared by SPCBs to control air pollution from17 polluted cities as per Hon’ble Supreme Court directionshould be properly implemented. An independent high powerexpert body should be setup by MoEF to oversee theimplementation.
10. The PM10/PM2.5 sampler used for the measurement of
PM10 and PM2.5 in ambient air required thorough
auditing with respect to calibration of the analyzers.
MoEF may notify suitable agencies, for example
CPCB, NEERI, and CSIO, which should be given
authority to audit the sampler. Only accredited
supplier’s instrument should be used for monitoring.
11. From the on-road vehicles fleet, grossly polluting
vehicles should be identified (which may be 5%-10% of
the total fleet), and they should be phased out.
12. To reduce high benzene levels in ambient air, vapour
recovery systems may have to be installed in petrol
dispensers and also benzene emission from two
wheelers need to be reduced. Impact studies on these
may be undertaken by oil companies and auto industry
and suitable action be taken.
13. As large number of DG Sets (diesel based small power
generating sets) is working in almost all cities due to bad
grid electricity supply, tighter norms need to be defined
for DG Sets.
14. About 40,000 mobile towers are installed in NCR region
and over 200,000 are installed in all over India. All mobile
towers have DG sets as backup power. Effort should be
made to reduce emission from these DG sets and DG
sets should be allowed to use only clean fuels /
technologies.
15. Development of mass rapid transportation systems. This
will reduce traffic congestion, lower personalized VKT,
and reduce soil and road dust re-suspension.
16. For 2 Wheelers, as the change in test cycle has shown
an increase in the emission values, the certifying agency
should establish the correlation.
17. NOx & HC values should be reported separately to show the
impact of NOx component.
18. For 3 Wheelers, the proposed emission values need to be made
more stringent.
19. In order to review the implementation of recommendations of
AFV&P-2025 and also to coordinate various recommended
studies, there it is recommended to form an empowered
committee with members drawn from all the stakeholders. The
scope of said committee must also include taking up following
studies:
• To review and suggest the emission norms for 2 & 3 wheelers aligning with
the proposed fuel specifications
• To propose the India specific fuel efficiency norms for all class of vehicles
commensurate with the fuel specifications.
• Assessment of impact of increasing octane no. from 91 to 95 on fuel
efficiency of gasoline vehicles.
• Assess the effect enhancing T95 of diesel fuel from 360 deg C to 370 deg C
on NOX & Particulate emission of diesel vehicles.
• Air quality management & source apportionment study to be carried out on
continuous basis and shall be part of periodic review for policy & measures
20. Fiscal strategy must look into following major issues:
– Judiciously setting differentiated tax rates
– To provide tax reduction/credits to refiners for providing lower sulfur fuels & additised fuels
– One time capital subsidy to meet the refinery costs.
– Incentives for non-polluting vehicles like electric/ hybrid/ fuel Cell based vehicles. This will help in increasing the penetration of these vehicles in public as well as in personal vehicles category.
FINAL RECOMMENDATION
Due to the fact mentioned about air quality, its impact onhuman health, it is strongly recommended to considerfollowing:-
� 50 ppm sulphur fuel should be made available all over Indiaby 2015
� 10 ppm sulphur fuel to be made available all over India by2020.
� Implementation of BS-IV fuel quality and vehicle emissionstandards by 2015 across the country
� Adoption of BS-V vehicular emission standards by 2017
� Adoption of BS-VI vehicular emission standards by 2019/20
� Commissioning of an effective I&M system across country toreplace or enhance the current PUC system
� Move towards world harmonized driving cycles
� Development of a fleet modernization programme
� Measures for reducing energy demand from the sector
� Advancement to Euro norms (Euro-4 and 5) for two- andthree-wheelers and adoption of separate norms for HC andNox
� Emission control from DG sets, use of clean fuel (CNG etc) inDGsets operated in metro cities
� Emission from other sources like power pants, SSI units alsoto be reduced to achieve ambient air quality standard
FUTURE REQUIREMENT IN THE FIELD OF POLLUTION CONTROL FOR OIL REFINERIES
1. New ambient air quality standard – monitoring using proper
sampling protocol and data reporting.
2. New emission standard (Furnace / Boiler / Captive Power
Plant, FCC and SRU) for SO2, NOx, CO, etc to be
implemented besides total SO2 emission load given as EC
Condition.
3. Fugitive emission standard for VOC and LDAR to be
implemented.
4. Contionuous emission monitoring system (CEM) to be installed
and calibration protocol to be followed strictly.
5. Continuous ambient air quality monitoring system to be
installed and calibration protocol be followed strictly.
6. EC compliance report and CEM / CAAQM data to be posted on
website of respective refinery.
7. CREP recommendation to be implemented.
8. Oily sludge management – co-processing of oily sludge in cement
plant / Bio-remediation of oily sludge
9. Sulphur balance to be prepared using actual monitoring data.
10. Volumatric flow rate in each stack to be monitored for total
emission load calculation.
11. Energy efficiency to be promoted to reduce GHG emission.
12. Compliance of all EC Conditions and reporting.
13. Water and waste water recycling .
14. Preparation of environmental statement and reporting.
15. Refineries to target to achieve 50 ppm sulphur fuel by 2015 and 10
ppm sulphur fuel by 2020 in order to reduce impact of air pollution
on human health.
