No: BCPL/BD/WBIGP/MoEFCC/EC-08 Aug 29, 2018 Ministry of ...environmentclearance.nic.in/writereaddata/... · Corporate office: 12th Floor, Knowledge Park, Hiranandani Business Park,

Bengal Concessions Private Limited

(Formerly known as H-Energy Pipeline Private Limited)

CIN :- U60231MH2016PTC271988

Regd Office: 514, Dalamal Towers, Nariman Point, Mumbai -400021, India

Corporate office: 12th Floor, Knowledge Park, Hiranandani Business Park, Powai, Mumbai – 400 076, India

T +91 22 2576 3705 F +91 22 2576 3777 W www.henergy.com

No: BCPL/BD/WBIGP/MoEFCC/EC-08 Aug 29, 2018

To

The Director (IA),

Ministry of Environment Forest and Climate Change

Indira Paryavaran Bhavan

Jor Bagh Road

New Delhi -110003

Sub: Application for amendment of Terms of Reference (TOR) for LNG Regasification Terminal

in Hooghly River at Kukrahati, East Medinipur district, West Bengal

Ref: Proposal No. IA/WB/IND2/69588/2017 dated Oct 5, 2017

File No. IA-J-11011/472/2017-IA-II(I)

Sir,

This is with reference to our proposal submitted vide Proposal No. IA/WB/IND2/69588/2017

dated Oct 5, 2017. In view of the few changes that we anticipate in the project now, we are

herewith submitting a revised Form-1, Pre-feasibility Report and proposed TOR.

In view of above we request you to consider the proposal and grant us a revised TOR with

amendments, if any.

Thanking you,

Yours Faithfully,

Abhirup Bhattacharya,

Director

For Bengal Concessions Private Limited

Encl:

1. Form-1

2. Pre-Feasibility Report

3. Proposed ToR

Bengal Concessions Private Limited

(Formerly known as H-Energy Pipeline Private Limited)

CIN :- U60231MH2016PTC271988

Regd Office: 514, Dalamal Towers, Nariman Point, Mumbai -400021, India

Corporate office: 12th Floor, Knowledge Park, Hiranandani Business Park, Powai, Mumbai – 400 076, India

T +91 22 2576 3705 F +91 22 2576 3777 W www.henergy.com

To Whomsoever it may concern

I, Abhirup Bhattacharya, hereby undertake that I am authorized to sign documents

on behalf of M/s Bengal Concessions Private Limited (BCPL) in my capacity as

Director, BCPL.

Abhirup Bhattacharya,

Director

For Bengal Concessions Private Limited

Date: 29th

Aug 2018

EXECUTIVE SUMMARY OF THE PROJECT

Bengal Concessions Private Limited (BCPL) is a subsidiary of H-Energy Renewables Private Limited

(HREPL), a company established with a vision to contribute to the economic growth of the country

by offering world class, environmentally safe and sustainable energy solutions. H-Energy Gateway

Private Limited, an affiliate of BCPL, is currently developing an LNG Floating Storage and

Regasification terminal at Jaigarh Port in Maharashtra and a cross-country pipeline connecting the

source to the National Gas Grid. Other affiliates of BCPL are involved in the business of providing

natural gas solutions including LNG Sourcing, re-gasification facilities, downstream deliveries based

on customer preference through suitable evacuation pipelines or by on-road LNG trucks. H-Energy

and its various affiliates endeavour to build world-class LNG infrastructure projects, which will

ensure a regular and sustainable supply of clean, environment-friendly natural gas fuel at strategic

locations on the east and west coasts of India.

To this regard, BCPL is planning to set up an LNG Storage and regasification terminal at Kukrahati,

West Bengal with a maximum capacity of 5 MMTPA As part of this project, BCPL intends to

construct a 600 m long jetty in the Hooghly River to moor a Floating Storage Unit (FSU)/Floating

Storage Regasification Unit (FSRU)/ Shuttle Vessels of suitable capacity. LNG received from the

Shuttle vessels shall be stored in FSU/FSRU/Storage Tanks on land and shall be regasified through

vaporizers provided either on the Jetty (Jetty Regasification System)/ Land(Land based

regasification system) or onboard the FSRU. The R-LNG thus produced shall be supplied to

customers through suitable onshore evacuation pipelines.

BCPL also intends to set up a truck loading facility at Kukrahati to transport LNG to customers

through Cryogenic road tankers. LNG shall also be reloaded in small vessels for bunkering of other

vessels. BCPL plans to commission this project by Q2, 2021.

1/12

APPENDIX I

(See Paragraph-6)

FORM 1

Note : If space provided against any parameter is inadequate, Kindly upload supporting document under 'Additional

Attachments if any' at the last part of the Form1. Please note that all such Annexures must be part of single pdf

document.

(I) Basic Information

S.No. Item Details

1. Name of the Project

LNG Regasification Terminal in

Hooghly River at Kukrahati, West Bengal

2. Project Sector Industrial Projects - 2

3. Location of the project Kukrahati, East Medinipur District, West Bengal

4.

Shape of the project land Block (Polygon)

Uploaded GPS file A nnexure-GPS file

Uploaded copy of survey of India Toposheet A nnexure-Survey of india toposheet

5. Brief summary of project Annexure-Brief summary of project

6. State of the project West Bengal

Details of State of the project

S.no State Name District Name Tehsil Name

(1.) West Bengal East Medinipur Sutahata - I

7. Town / Village Matiramchak

8.

Plot/Survey/Khasra

No.

Plot no. 7 to 108,

104/139,7/140,41/141,41/142,41/143,51/144,51/145,53/146,54/147,78/148,100/149,100/150,5/151P,

14/152, 16/153, 20/154, 26/156, 88/161, 25/162 Plot no. 135 to 146, 149P, 139/694, 66, 67, 70, 72, 73, 50, 55, 56, 46, 47, 48, 26 - 31, 13 – 17, 85, 86, 88, 211, 182, 14, 19, 20, 21, 22, 25, 26, 27, 1, 7, 80, 82, 83, 86, 87, 88, 89, 90, 91, 92, 98, 97, 99

9. S. No. in the schedule 6(a) Oil & gas transportation pipe line (crude and refinery/

petrochemical products), including LNG Terminal

10.

Proposed capacity/area/length/tonnage to be

handled/command area/lease area/number or

wells to be drilled

The proposed LNG terminal is initially envisaged to handle 0.3-3

MMTPA (Million Metric Tonnes Per Annum) of Regasified Liquefied

Natural Gas (RLNG) /LNG during the first 5-6 years of operation and it

capacity will be increased up to 5.0 MMTPA of RLNG /LNG.

11. New/Expansion/Modernization New

12. Category of project i.e. 'A' or 'B' A

13. Does it attract the general condition? If yes,

please specify No

15. Does it attract the specific condition? No

16. Is there any litigation pending against the project? No

17. Nearest railway station along with distance in kms. Bajitpur, 4.5 km

18. Nearest airport along with distance in kms Kolkata Airport, 137 km

19. Nearest Town/City/District Headquarters along

with distance in kms Mahisadal and Haldia , 12.5 km

20. Details of alternative sites examined shown on a

Topo sheet

(Uploaded details)

No

http://environmentclearance.nic.in/writereaddata/Online/TOR/18_Sep_2017_175115583BSQVFX0QAnnexure-Siteontoposheet.pdf

2/12

21. Whether part of interlinked projects? No

Activity 1 Construction, operation or decommissioning of the Project involving actions, which will cause physical changes

in the locality (topography, land use, changes in water bodies, etc.)

S.No Information/Checklist confirmation

Yes/No

Details there of (with approximate

quantities/rates, wherever possible) with

source of information data

1.1

Permanent or temporary change in land use, land cover or

topography including increase in intensity of land use (with respect

to local land use plan)

Yes

The proposed project site is divided into two parts.

One part is a vacant land earlier allotted for the

construction of shipbuilding unit. The construction of

LNG regasification terminal will have the same land

use, ie. industrial activity.

The second part of the land is currently being used

as a brick-kiln. The construction of LNG regasification

terminal shall increase the intensity of land use of

this land.

1.2 Clearance of existing land, vegetation and buildings? No

The proposed site has no vegetation or trees and

would therefore require no specific clearance. BCPL shall also develop greenbelt around the periphery of the project site.

1.3

Creation of new land uses?

No

One part of the proposed site was earmarked for

industrial use earlier and leased for setting up of a

shipyard. Now BCPL is procuring this land for

construction of LNG Regasification Terminal. The

other part of the land is also under industrial used as

brick kiln is located. Both the activities can be

classified as industrial activities and hence there is

no change in land use.

1.4

Pre-construction investigations e.g. bore houses, soil testing?

Yes

Geotechnical investigations involving borehole data

are underway to ascertain the properties of land for

construction purpose. Bathymetry survey was

conducted in the river at the site of the project. Met-

ocean data being collected at site to carry out

various studies for jetty and other facilities which

proposed on the river front.

22. Whether the proposal involves approval/clearance

under the Forest (Conservation)Act,1980?


under the wildlife (Protection)Act,1972?


under the C.R.Z notification,2011? No

25. Whether there is any Government Order/Policy

relevent/relating to the site?

26. Whether there is any litigation pending against the

project and/or land in which the project is No

proposed to be set up?

27. Project Cost(in lacs)

200000

No

No

No

3/12

1.5

Construction works?

Yes

LNG receiving Jetty, Control Room, Site offices,

Metering, Pig Launching Facilities, designed Cold/Hot

flare, Onshore LNG Tanks, Truck Reloading Facility,

Gen-sets, Fire Fighting Facility, UPS, Security

installations, Site infra, internal roads, intake

pumping station and piping, instrumentation,

electrical and other equipment. Vaporizers for LNG

regasification shall be installed either on the jetty or

on the project site. LNG/R-LNG Unloading Arms, LNG

Cryogenic pipeline/R-LNG pipeline.

1.6 Demolition works?

Yes

Only the temporary structures of the brick-kiln shall be demolished. There is no settlement or hutments at the site.

1.7

Temporary sites used for construction works or housing of

construction workers?

Yes

Construction workers will be sourced from nearby

areas. However, temporary construction camp site

will be constructed within the proposed project site.

The drinking water, sanitation facility, etc., will be

provided.

1.8

Above ground buildings, structures or earthworks including linear

structures, cut and fill or excavations and fill or excavations

Yes

Control Room, Site offices, Shore protection,

Metering, Pressure Reduction, Pig Launching

Facilities, designed Cold/Hot flare, Onshore LNG

Tanks, Truck Reloading Facility, buildings for housing

Gen-sets, UPS, Electrical and Other equipments. Fire

Fighting Facility, Security installations, Infra Work

and piping, instrumentation, Vaporizers for LNG

regasification shall be installed either on jetty or on

project site. LNG/R-LNG Unloading Arms, LNG

Cryogenic pipeline/R-LNG pipeline. The site will be

graded properly to safegrade elevation. The

excavated material will be used for backfilling.

1.9

Underground works including mining or tunneling?

Yes

Underground evacuation pipeline(s) (at 5.0 m

maximum depth) will be constructed from LNG

terminal to consumers/gas grid in Haldia.

Crossing of Hooghly river using Horizontal Directional

Drilling Method or Direct piping system or any other

equivalent method from Kukrahati site to a suitable

location near Raichak Jetty.

1.10 Reclamation works? Yes Necessary Reclamation work to ensure shore

protection of the project site shall be done. No

reclamations are proposed inside river.

1.11

Dredging?

Yes

The jetty would normally be located at a depth

suitable to moor the FSRU/FSU/LNG shuttle vessel to

the jetty. The prevailing depths near the project site

in the river channel is >10m and there may not be

any dredging required. However, if the jetty is to be

located at shallower depths < 7m, based on

recommendation from the Kolkata Port Trust (KoPT)

dredging would be required and dredge material

would be safely disposed as per existing practices of

KoPT.

1.12

Offshore structures?

No

A Jetty and an approach trestle on piles shall be

constructed in the Hooghly river. A Trestle shall

connect the jetty to the project site. Both LNG and R-

LNG Unloading Arms and pipelines shall be mounted

on the trestle. The Vaporizers for LNG regasification

shall be Intermediate fluid vaporizer / Ambient air

vaporizer which shall be installed either on the

FSRU/jetty/ project site. No offshore structures are

required as the site is located in the river.

4/12

1.13

Production and manufacturing processes?

Yes

The LNG onboard the FSU/FSRU Structure shall be

vaporized using the Vaporizers which shall be

installed either onboard the FSRU or on the jetty or

on the project site. R-LNG will then be evacuated

through evacuation pipeline(s).

Further, LNG shall be directly offloaded to LNG

Storage Tanks on the Project site and shall be used

for loading LNG Road Tankers.

1.14

Facilities for storage of goods or materials?

Yes

LNG will be stored in cargo tanks of

FSRU/FSU/Onshore tanks. Each cargo storage tank

shall be equipped with block valves on the filling

lines, which allow isolating the tank in case of

emergency. Further, as part of the Truck Loading

facilities, additional onshore LNG storage tank/s shall

be installed at the project site.

1.15

Facilities for treatment or disposal of solid waste or liquid effluents?

Yes

Regasification system can be either river water or

glycol based IFVs/AAV. In case of IFV, the water will

be discharged back to the river at temperature lower

than the ambient. Water from the vaporization

system will be discharged after maintaining an

acceptable temperature gradient as per World Bank

Guidelines. Ballast water will be discharged at

ambient temperature. Bilge water will be treated

onboard the FSRU/FSU before discharge. The sewage

generated will be treated before discharge.

1.16 Facilities for long term housing of operational workers? No The residential facilities will be provided in nearby

locality for operational workers.

1.17 New road, rail or sea traffic during construction or operation? No Existing road and rail network will be used .Though

there is limited passenger launches movement in

the river, these movements are along the river

course and safety distances are available for the

launches. River width at the jetty site is more than

2km.River crossing by R-LNG pipeline shall be at

least 5.0 m below the riverbed and shall be done

using Horizontal Directional Drilling Method or Direct

Piping System. This process will not impact any

road/rail/river traffic during construction or

operation.

1.18 New road, rail, air water borne or other transport infrastructure

including new or altered routes and stations, ports, airports etc?

No The site is well-connected through Rail road network

for transporting materials to the site. As the site is adjacent to Hooghly river, river route will be utilized for transport of construction materials as well as LNG vessels.

1.19

Closure or diversion of existing transport routes or infrastructure

leading to changes in traffic movements?

No

Closure or diversion of existing transport routes is

not required for the proposed project.

1.20

New or diverted transmission lines or pipelines?

Yes

R-LNG evacuation pipeline(s) will be laid onshore to

evacuate the R-LNG from facility to consumers/gas

grid.

River crossing by R-LNG pipeline shall be at least 5.0

m below the riverbed and shall be done using

Horizontal Directional Drilling Method or Direct piping

system. This process will not impact any

transmission lines or pipelines during construction or

operation.

1.21 Impoundment, damming, culverting, realignment or other changes

to the hydrology of watercourses or aquifers? No Not envisaged

5/12

1.22

Stream crossings?

Yes

River crossing will be required for taking the R-LNG

evacuation pipeline to the opposite bank of the river

for supply to customers.

River crossing by R-LNG pipeline shall be laid at least

5.0 m below the riverbed and shall be done using

Horizontal Directional Drilling Method or Direct Piping

System. This process will not impact any

road/rail/river traffic during construction or

operation.

1.23

Abstraction or transfers of water from ground or surface waters?

Yes

~100 KLD river water for civil work. For HDD,

bentonite with water as the Floating medium sourced

separately. For Hydro testing ~10000 m3 water.

~10,000 m3 / hr of river water initially for regas.

When demand ramps up, Max 25,000 m3/hr (@5000

m3/hr/1 MMTPA LNG).Discharge standards shall be

met. 150 m3/hr for fire water storage system, 2000

m3/hr river water for auxiliary cooling system and a

maximum of 1500 m3/hr river water as ballast

water. 2-3 KLD groundwater for workers.

1.24

Changes in water bodies or the land surface affecting drainage or

runoff?

No

There is a small canal in between the two parts of

land proposed for the site. The same shall be

retained. However since the project site is on either

side of this small canal, required above ground

piperack / underground crossing shall be built to

transport LNG/R-LNG/other utilities between the two

project sites. Further, required overground cable

trays / underground cable crossings shall be done to

connect both the plots for electrical /

instrumentation cables.

1.25

Transport of personnel or materials for construction, operation or

decommissioning?

Yes

Construction materials will be transported to site

through existing road network / water ways along

Hooghly river. During operational phase, LNG will be

transported using LNG vessel through Hooghly River

to the LNG Storage Tanks situated in the FSU/FSRU

Onshore.

1.26 Long-term dismantling or decommissioning or restoration works? No Not envisaged

1.27 Ongoing activity during decommissioning which could have an

impact on the environment? No Not envisaged

1.28

Influx of people to an area in either temporarily or permanently?

No

During the construction period, ~ 500 skilled/semi

skilled/unskilled workers will be engaged. During the

operation phase, ~50 skilled/unskilled persons of

Indian/Foreign origin will be stationed by the O&M

Contractor on the FSU/FSRU. Their accommodation

shall be onboard the vessel. At the site, approx. 50-

100 skilled/semi skilled persons of Indian/Foreign

origin would be required to operate the onshore

facility. The accommodation facilities for these people

will be provided nearby.

1.29 Introduction of alien species? No Not envisaged

1.30 Loss of native species or genetic diversity? No Not envisaged

1.31 Any other actions? No Not envisaged

6/12

2 Use of Natural resources for construction or operation of the Project (such as land, water, materials or energy, especially any resources which are non-renewable or in short supply):


Yes/No

Details thereof (with approximate

quantities/rates, wherever possible)

with source of information data

2.1

Land especially undeveloped or agricultural land (ha)

No

The project site is not currently used for

any agricultural activity. Before

possession, part of the site was allotted

for industrial use while the other part is

being used as a brick kiln.

2.2 Water (expected source & competing users) unit: KLD Yes ~ 10,000 m3 / hr of river water would be

required for regasification initially. When

demand ramps up, Maximum of 25,000

m3/hr of river water would be required

for regasification (@5000 m3/hr/1

MMTPA LNG). After meeting the

discharge standards, these waters will be

discharged back into the river. The river

water from Hooghly, near proposed

project site is being utilized for municipal

supply, industrial supply. This water

requirement may not have impact on

competing users.

2.3 Minerals (MT) No Not envisaged

2.4

Construction material – stone, aggregates, sand / soil (expected source – MT)

Yes

Construction Material including but not

limited to stone, sand/soil, aggregates

shall be used during the construction

stage of the project. These items shall be

sourced locally as well as from outside

sources as per the requirement.

2.5 Forests and timber (source – MT) No Not envisaged

2.6 Energy including electricity and fuels (source, competing users) Unit: fuel (MT),energy (MW)

Yes Approximately 3MW power required

during construction which shall be met

either by local grid or Diesel Gensets.

During operation stage the power

requirement for the facilities on the jetty

and site would be met from West Bengal

State Electricity Board (WBSEB) or from

the power generated from Boil off gas

from the FSRU/FSU or through gas/diesel

gensets. The FSRU/FSU shall be self

sufficient upto 40 MW. In case of the land

based tank and vaporizer option the

power requirement would be 20 MW.

2.7 Any other natural resources (use appropriate standard units) No Not envisaged

7/12

3 Use, storage, transport, handling or production of substances or materials, which could be harmful to human health or the environment or raise concerns about actual or perceived risks to human health


Yes/No




3.1

Use of substances or materials, which are hazardous (as per MSIHC

rules) to human health or the environment (flora, fauna, and water

supplies

No

The facility shall be used for storage and

distribution of Liquefied natural gas and

R-LNG. In case of normal operation,

LNG/ R-LNG does not cause any impact

on human health and impact on flora and

fauna. However, in case of any incident

related to release of gas, fire may cause

serious/fatal impact on nearby human

population and ecological environment.

3.2 Changes in occurrence of disease or affect disease vectors (e.g. insect

or water borne diseases) No Not envisaged

3.3

Affect the welfare of people e.g. by changing living conditions?

Yes

During the construction period, approx.

500 skilled/semi skilled/unskilled workers

will be engaged by various contractors on

temporary basis. During the operation

phase, approx. 50 persons will be

stationed by the O&M Contractor on the

FSU/FSRU. Their accommodation shall be

onboard the vessel.

At the site, approx. 50-100 persons

would be required to operate the onshore

facility. Necessary Health safety &

Environmental (HSE) policy shall be in

place during Construction and operation

stages.

3.4 Vulnerable groups of people who could be affected by the project e.g.

hospital patients, children, the elderly etc. No Not envisaged

3.5 Any other causes No Not envisaged

4 Production of solid wastes during construction or operation or decommissioning (MT/month)

S.No Information/Checklist confirmation Yes/No Details thereof (with approximate



4.1

Spoil, overburden or mine wastes

No

No Spoil, overburden or mine wastes will

be generated. However, excavated and

dredged material will be generated

during construction of jetty and vessel

approach path. The excavated materials

will be utilized for filling of site and

dredged materials generated shall be

disposed in the KOPT disposal site.

4.2

Municipal waste (domestic and or commercial wastes)

Yes

During the construction phase of the

project, approximately 20-25 kg/day and

during operational phase 25-30 kg/day of

solid waste will be generated. The MSW

will be disposed in the nearby municipal

dumping ground.

4.3

Hazardous wastes (as per Hazardous Waste Management Rules)

Yes

During construction phase some used oil

will be generated from equipment and

machineries and DG set. These will be

disposed as per Hazardous and Other

Wastes (Management and Transboundary

Movement) Rules 2016.

4.4 Other industrial process wastes No Not envisaged

8/12

4.5 Surplus product No Not envisaged

4.6 Sewage sludge or other sludge from effluent treatment No Sludge generated will be utilised as

manure in proposed greenbelt plantation

area.

4.7

Construction or demolition wastes

Yes

Construction debris (earth and concrete)

will be utilised for construction of site

internal roads. Recyclable materials will

be sold to vendor.

4.8 Redundant machinery or equipment No Not envisaged

4.9 Contaminated soils or other materials No Not envisaged

4.10 Agricultural wastes No Not envisaged

4.11 Other solid wastes No Not envisaged

5 Release of pollutants or any hazardous, toxic or noxious substances to air(Kg/hr)

S.No

Information/Checklist confirmation

Yes/No




5.1

Emissions from combustion of fossil fuels from stationary or mobile

sources

Yes

During construction, heavy machineries

like crane, digging equipment, piling

equipment shall give rise to emission

from combustion of fossil fuel. During

operation, some emission is expected

from heavy/light vehicles which shall

have valid PUC certificate. Some

emissions are expected during the

FSRU/FSU operation during generation of

power in the Gas/Diesel Gensets on

board/ the site. All these emissions would

be treated and controlled to meet the

standard emission norms.

5.2 Emissions from production processes No Not envisaged. However, during

commissioning and Maintenance activities, some amount of venting of R-LNG would be required to ensure readiness of plant and equipment.

5.3 Emissions from materials handling including storage or transport Yes During commissioning and Operation,

some amount of venting of R-LNG would be required. A suitable cold/ automatic flare system for safe disposition shall be planned at site during the detail design stage. Fugitive emissions from mechanical seals, bearings, valves, instrumentation tubings, pumps, exchangers, gensets, compressors, filters, pig receiver/ launchers etc. is expected. Some emission is expected from operation of heavy/light vehicles.

5.4

Emissions from construction activities including plant and equipment

Yes

During construction period, heavy

machineries like crane, digging

equipment, piling equipment is likely to

give rise to some emission from

combustion of fossil fuel. Fugitive dust

emissions are envisaged during earth

work. Appropriate dust suppression

measures will be taken to minimise the

impact.

9/12

5.5

Dust or odours from handling of materials including construction

materials, sewage and waste

No

Dust emission likely to occur while

handling of Construction materials.

However, odour will not be generated. Appropriate dust suppression measures

will be taken to minimise the impact The

sewage generated will be treated before

discharge.

5.6 Emissions from incineration of waste No Not envisaged

5.7 Emissions from burning of waste in open air (e.g. slash materials,

construction debris) No Not envisaged

5.8 Emissions from any other sources No Not envisaged

6 Generation of Noise and Vibration, and Emissions of Light and Heat:


Yes/No




6.1

From operation of equipment e.g. engines, ventilation plant, crushers

Yes

Noise will be generated during

construction. The machinery used will

adhere to national standards and

emissions shall be within stipulated

limits. For FSU/FSRU, main emission

sources include River water process

pumps; River water cooling pumps;

Hypochlorite dosing system; Power

Generation system; Sanitary discharge

pumps; Booster pumps; Cooling water

unit and Compressors; Diesel Gensets;

Gas Gensets, engines; Fire water Pumps,

HDD Machine. Noise level will be

maintained to 75 dB.

6.2

From industrial or similar processes

Yes

During operational phase, noise will be

generated from pump house and other

onshore facilities. For FSU/FSRU, main

emission sources include River water

process pumps; Hypochlorite dosing

system; Power Generation system;

Sanitary discharge pumps; Booster

pumps; Cooling water unit and

Compressors; Diesel Gensets; Gas

Gensets, engines; Fire water Pumps, HDD

Machine. Noise level will be maintained to

75 dB.

6.3

From construction or demolition

Yes

• Diesel Generators, 75 dB(A) • Heavy

Duty Construction equipment: 75 to 95

dB(A) • Vehicular Noise: 85 dB(A) (at the

edge from the centerline of the road)

Appropriate necessary control measures

will be adopted to minimize the

emissions from different sources.

6.4 From blasting or piling Yes

Piling activities are envisaged during

construction of jetty, trestle and facilities on site. Approximately 75 to 95 dB (A) of noise is expected during piling.

6.5 From construction or operational traffic Yes Increase in noise is expected due to

movement of vehicles.

due

to

6.6 From lighting or cooling systems No

Lighting system shall be installed on the

project site, trestle as well as the jetty. However, no noise emission is envisaged from the lighting system. HVAC shall be installed at the project site for the various offices/control room/security room etc., and shall have “not recordable” noise emissions.

6.7 From any other sources No Not envisaged

10/12

7 Risks of contamination of land or water from releases of pollutants into the ground or into sewers, surface

waters, groundwater, coastal waters or the sea:

S.No Information/Checklist confirmation Yes/No Details thereof (with approximate quantities/rates, wherever possible) with source of information data)

7.1 From handling, storage, use or spillage of hazardous materials No Not envisaged

7.2

From discharge of sewage or other effluents to water or the land

(expected mode and place of discharge)

No

During construction, domestic waste

water will be treated through septic tank

and soak pit. During operational phase,

water used for regasification, ballast

water, Water from the vaporization

system will be discharged after

maintaining an acceptable temperature

gradient. The bilge water and sewage will

be treated and then will be discharged

into river or in to the municipal sewage

system. Discharge of treated water may

not cause significant impact on receiving

surface water body.

7.3

By deposition of pollutants emitted to air into the land or into water

No

The emission from regasification system,

flaring and fugitive emissions from

storage and handling of LNG to air during

operational phase are not expected to be

significant. All these emissions would be

treated and controlled to meet the

standard emission norms. The risk of

contamination of land or water from such

emissions is therefore low to none.

7.4 From any other sources No Not envisaged

7.5 Is there a risk of long term build up of pollutants in the environment

from these sources? No

Adequate risk reduction measures will be

taken.

8 Risk of accidents during construction or operation of the Project, which could affect human health or the

environment


Yes/No




The main risk for safety and environment

is related to the handling of LNG and

pressurized natural gas (NG). LNG hazards result from three of its properties: cryogenic temperatures, dispersion characteristics, and flammability characteristics. In order to cope with these risks, International Maritime Organization (IMO) issues the International Code for the Construction and Equipment of Ships Carrying Liquefied Gases in Bulk (normally referred as IGC Code).

8.1 From explosions, spillages, fires etc from storage, handling, use or

production of hazardous substances

Yes

8.2 From any other causes No Not envisaged

11/12

The Project Site falls under Seismic Zone

IV classified as damage risk zone as per

IS 1893-2002. The design of the facility

will be in accordance with relevant IS

Codes. Suitable seismic coefficients

in horizontal and vertical directions

respectively, would be adopted while

designing the structures as per NBC/ IS

Codes and other statutory norms. The

site is falling in the cyclone and flood

prone area. Required drainage and Flood

control measures will be taken to protect

the site.

Could the project be affected by natural disasters causing

8.3 environmental damage (e.g. floods, earthquakes, landslides, Yes

cloudburst etc)?

9 Factors which should be considered (such as consequential development) which could lead to environmental

effects or the potential for cumulative impacts with other existing or planned activities in the locality

S.No

Information/Checklist confirmation

Yes/No




9.1 Lead to development of supporting. facilities, ancillary development

or development stimulated by the project which could have impact

on the environment e.g.:

Supporting infrastructure (roads, power supply,waste or waste

water treatment, etc.)

housing

development

extractive industries

supply industries

Other

Yes The project is envisaged keeping in mind

the industrial and domestic consumers of

the region. The project is strategic in

nature and when implemented, will

benefit not only the eastern states of

India but also the neighbouring country

of Bangladesh.

9.2 Lead to after-use of the site, which could have an impact on the

environment No Not envisaged

9.3 Set a precedent for later developments Yes It will accelerate the industrial growth in

the region.

9.4

Have cumulative effects due to proximity to other existing or planned

projects with similar effects

No

There are no major industries in 10 km

study area, hence cumulative impacts

due to the proposed project is not

envisaged.

(III) Environmental Sensitivity

S.No

Areas

Name/Identity

Aerial distance (within 15km.)

Proposed project location

boundary

1

Areas protected under international conventions, national or

local legislation for their ecological, landscape, cultural or other

related value

No

There is no protected area like

National Park, Wildlife Sanctuary,

Biosphere Reserve, etc.

2

Areas which are important or sensitive for ecological reasons -

Wetlands, watercourses or other water bodies, coastal zone,

biospheres, mountains, forests

No

The proposed site is not located in

the eco-sensitive zone.

3

Areas used by protected, important or sensitive species of flora

or fauna for breeding, nesting, foraging, resting, over wintering,

migration

No

Nil

4 Inland, coastal, marine or underground waters Yes Adjacent to Hooghly River

5 State, National boundaries No Nil

6

Routes or facilities used by the public for access to recreation or

other tourist, pilgrim areas

No

Raichak- Kukrahati ferry terminal

route is approx.1.5 km from site.

Kukrahati bus stand is located at

about 2 Km from site.

12/12

7 Defence installations No None

8

Densely populated or built-up area

No

Mahisadal town is approximately 12.5

km site and Haldia town is 12.5 km

from the site.

9

Areas occupied by sensitive man-made land uses (hospitals,

schools, places of worship, community facilities)

Yes

Community facilities like hospitals,

schools, temples/mosques are

located in Kukrahati village which is

about 2km from the site. There are

no sensitive man-made land

uses/facilities in the immediate

vicinity of the site.

10

Areas containing important, high quality or scarce

resources.(ground water resources,surface

resources,forestry,agriculture,fisheries,tourism,minerals)

No

Nil

11 Areas already subjected to pollution or environmental

damage.(those where existing legal environmental standards are

exceeded)

No Nil

12 Areas susceptible to natural hazard which could cause the project

to present environmental problems (earthquakes, subsidence,

landslides, erosion, flooding or extreme or adverse climatic

conditions) similar effects

Yes The site is falling in the cyclone and

flood prone area. The project area

falls in Zone IV, which has high

probability of seismic activities.

(IV) PROPOSED TERMS OF REFERENCE FOR EIA STUDIES

1 Uploaded Terms of Reference(TOR) File Annexure-TOR file

2 Uploaded scanned copy of covering letter Annexure-scanned copy of covering letter

3 Uploaded Pre-Feasibility report(PFR) Annexure-PFR

(V) Undertaking

The aforesaid application and documents furnished here with are true to my knowledge

V.

(i) Name of Applicant Abhirup Bhattacharya

Designation Director

Name of Company(Applicant Name should not BENGAL CONCESSIONS PRIVATE LIMITED

be given here)

Address 514, Dalamal Towers, 211, FPJ Marg, Nariman point, Mumbai, India

29th August 2018 Pre-Feasibility Report Private and Confidential

1

Rev. 0

LNG Regasification Terminal in `


Document No. BD/BCPL/WBIGP/EC/001


2

Table of Contents 1. EXECUTIVE SUMMARY ................................................................................................................................ 5

2. INTRODUCTION/BACKGROUND OF THE PROJECT...................................................................................... 5

2.1. IDENTIFICATION OF THE PROJECT .............................................................................................................. 5

2.2. NEED FOR THE PROJECT ............................................................................................................................. 6

2.3. DEMAND – SUPPLY GAP ........................................................................................................................... 10

2.4. IMPORTS vs. INDIGENOUS PRODUCTION................................................................................................. 11

2.5. EXPORT POSSIBILITY ................................................................................................................................. 11

2.6. DOMESTIC / EXPORT MARKETS ................................................................................................................ 12

2.7. EMPLOYMENT GENERATION (DIRECT AND INDIRECT) ............................................................................. 14

3. PROJECT DESCRIPTION ............................................................................................................................. 15

3.1. TYPE OF PROJECT ...................................................................................................................................... 15

3.2. SITE LOCATION ......................................................................................................................................... 15

3.3. DETAILS OF ALTERNATE SITES .................................................................................................................. 17

3.4. SIZE OF OPERATION .................................................................................................................................. 17

3.5. PROCESS DETAILS ..................................................................................................................................... 18

3.6. PROJECT FACILITIES .................................................................................................................................. 25

3.6.1. JETTY ....................................................................................................................................................... 25

3.6.2. MARINE UNLOADING ARMS ................................................................................................................... 25

3.6.3. ONSHORE FACILITIES .............................................................................................................................. 25

3.6.4. ONSHORE STORAGE TANKS .................................................................................................................... 27

3.6.5. OFF-LOADING SYSTEM ............................................................................................................................ 28

3.6.6. LNG STORAGE ......................................................................................................................................... 28

3.6.7. LNG REGASIFICATION ............................................................................................................................. 29

3.6.8. BOG HANDLING AND FUEL GAS SYSTEM ................................................................................................ 32

3.6.9. WATER SYSTEM ....................................................................................................................................... 33

3.6.10. VENTING SYSTEM .................................................................................................................................. 33

3.6.11. NITROGEN SYSTEM ............................................................................................................................... 33

3.6.12. EVACUATION PIPELINE SYSTEM ............................................................................................................ 34

3.6.12.1. HORIZONTAL DIRECTIONAL DRILLING .......................................................................................... 34

3.6.12.2. DIRECT PIPE METHOD ................................................................................................................... 35

3.7. RAW MATERIAL REQUIRED ...................................................................................................................... 35

3.8. RESOURCE OPTIMIZATION ....................................................................................................................... 35

3.9. AVAILABILITY OF WATER, ITS SOURCE AND ENERGY REQUIREMENT ...................................................... 35


3

3.10. WASTE PRODUCTION &DISPOSAL ............................................................................................................ 36

3.11. SCHEMATIC REPRESENTATION OF THE FACILITY ..................................................................................... 39

3.12. NOISE EMISSIONS ..................................................................................................................................... 40

3.13. EMISSION DATA ........................................................................................................................................ 41

3.13.1. EMISSIONS TO ATMOSPHERE ............................................................................................................... 42

3.13.2. DISCHARGE TO WATER.......................................................................................................................... 44

4. SITE ANALYSIS ........................................................................................................................................... 46

4.1. CONNECTIVITY .......................................................................................................................................... 46

4.2. LAND FORM AND LAND OWNERSHIP ....................................................................................................... 46

4.3. TOPOGRAPHY ........................................................................................................................................... 46

4.4. EXISITING LAND USE PATTERN ................................................................................................................. 47

4.5. DRAFT AT SITE .......................................................................................................................................... 47

4.6. EXISTING INFRASTRUCTURE ..................................................................................................................... 47

4.7. SOIL CLASSIFICATION ................................................................................................................................ 47

4.8. CLIMATIC DATA FROM SECONDARY SOURCES ......................................................................................... 47

4.8.1. RAINFALL ................................................................................................................................................. 47

4.8.2. TEMPERATURE ........................................................................................................................................ 48

4.8.3. RELATIVE HUMIDITY ............................................................................................................................... 49

4.9. METOCEAN CONDITIONS ......................................................................................................................... 49

4.9.1. WIND ....................................................................................................................................................... 49

4.9.2. WAVE AND TIDE ...................................................................................................................................... 49

4.9.3. CURRENT ................................................................................................................................................. 49

4.9.4. SEA SURFACE TEMPERATURE ................................................................................................................. 50

4.9.5. pH ............................................................................................................................................................ 50

4.9.6. SALINITY .................................................................................................................................................. 50

4.9.7. SOCIAL INFRASTRUCTURE ....................................................................................................................... 50

5. PLANNING BRIEF ....................................................................................................................................... 50

5.1. PLANNING CONCEPT ................................................................................................................................ 50

5.2. POPULATION PROJECTION ....................................................................................................................... 51

5.3. LAND USE PLANNING ............................................................................................................................... 51

5.4. ASSESSMENT OF INFRASTRUCTURE DEMAND ......................................................................................... 51

5.5. AMENITIES/FACILITIES .............................................................................................................................. 51

6. PROPOSED INFRASTRUCTURE .................................................................................................................. 52

6.1. INDUSTRIAL AREA ..................................................................................................................................... 52

6.2. RESIDENTIAL AREA ................................................................................................................................... 52


4

6.3. GREEN BELT .............................................................................................................................................. 52

6.4. SOCIAL INFRASTRUCTURE ........................................................................................................................ 52

6.5. CONNECTIVITY .......................................................................................................................................... 53

6.6. DRINKING WATER MANAGEMENT ........................................................................................................... 53

6.7. FIRE WATER STORAGE SYSTEM MANAGEMENT ...................................................................................... 53

6.8. SEWAGE SYSTEM ...................................................................................................................................... 54

6.9. INDUSTRIAL & SOLID WASTE MANAGEMENT .......................................................................................... 54

6.10. POWER REQUIREMENT & SUPPLY/SOURCE ............................................................................................. 54

7. REHABILITATION AND RESETTLEMENTS (R&R) PLAN ............................................................................... 55

8. PROJECT SCHEDULE AND COST ESTIMATES ............................................................................................. 55

8.1. SCHEDULE ................................................................................................................................................. 55

8.2. PROJECT COST .......................................................................................................................................... 56

9. ANALYSIS OF THE PROPOSAL.................................................................................................................... 56

10. HEALTH, SAFETY, ENVIRONMENT AND COMMUNITY .............................................................................. 57

11. CODES AND STANDARDS .......................................................................................................................... 59


5

1. EXECUTIVE SUMMARY

Bengal Concessions Private Limited (BCPL) is a subsidiary of H-Energy Renewables Private

Limited (HREPL), a company established with a vision to contribute to the economic growth of

the country by offering world class, environmentally safe and sustainable energy solutions. H-

Energy Gateway Private Limited, an affiliate of BCPL, is currently developing an LNG Floating

Storage and Regasification terminal at Jaigarh Port in Maharashtra and a cross-country pipeline

connecting the source to the National Gas Grid. Other affiliates of BCPL are involved in the

business of providing natural gas solutions including LNG Sourcing, re-gasification facilities,

downstream deliveries based on customer preference through suitable evacuation pipelines or

by on-road LNG trucks. H-Energy and its various affiliates endeavour to build world-class LNG

infrastructure projects, which will ensure a regular and sustainable supply of clean,

environment-friendly natural gas fuel at strategic locations on the east and west coasts of

India.

To this regard, BCPL is planning to set up an LNG Storage and regasification terminal at

Kukrahati, West Bengal with a maximum capacity of 5 MMTPA. As part of this project, BCPL

intends to construct a 600 m long jetty in the Hooghly River to moor a Floating Storage Unit

(FSU)/Floating Storage Regasification Unit (FSRU)/ Shuttle Vessels of suitable capacity. LNG

received from the Shuttle vessels shall be stored in FSU/FSRU/Storage Tanks on land and shall

be regasified through vaporizers provided either on the Jetty (Jetty Regasification System)/

Land (Land based regasification system) or onboard the FSRU. The R-LNG thus produced shall

be supplied to customers through suitable onshore evacuation pipelines.

BCPL also intends to set up a truck loading facility at Kukrahati to transport LNG to customers

through Cryogenic road tankers. LNG shall also be reloaded in small vessels for bunkering of

other vessels. BCPL plans to commission this project by Q2, 2021.

2. INTRODUCTION/BACKGROUND OF THE PROJECT

2.1. IDENTIFICATION OF THE PROJECT

In order to meet the LNG/RLNG demands in West Bengal and Western Bangladesh, BCPL

proposes to develop an LNG storage and regasification terminal at Kukrahati in West Bengal.

The project is envisaged keeping in mind the industrial and domestic consumers of the region.

The project is strategic in nature and when implemented, will benefit not only the eastern

states of India but also the neighboring country of Bangladesh. BCPL’s project location is in


6

close proximity to Industrial regions in Eastern India and in Bangladesh, who shall be the

primary consumers of RLNG from the project.

2.2. NEED FOR THE PROJECT

Demand for natural gas in India is expected to increase manifold in the future given its

competitive edge over other fuels in terms of environmental benefits, efficiency and pricing

against liquid fuels. Historically, power and fertilizer sectors in India have been the largest

consumers of gas. Based on this and certain other factors, these sectors received priority in

allocation of gas. Infrastructure was also developed considering the needs of these sectors.

However, for the other sectors, the development of supply infrastructure has remained

limited. These sectors are therefore still at a nascent stage of gas use but show a huge and

growing appetite for the fuel.

Currently India has four regasification terminals with a total capacity of approximately 31.7

MMTPA. In addition to this, the proposed terminals and the ones under construction are likely

to enhance the regasification capacity to the tune of another 37 MMTPA. Till date, over 87

Geographical areas have been authorized by PNGRB for City Gas Distribution (CGD) operations

in various cities. Also, India currently has an operating natural gas pipeline for infrastructure of

over 16470 kms and capacity of about 387 MMSCMD. This network is expected to expand to

around 29,369kms of pipelines with a total design capacity of around 879 MMSCMD in next 5-6

years taking the country close to the formation of Natural gas grid connecting all major

demand and supply centers in India. This will ensure wider and uniform availability of gas

across all regions for social and economic progress. Overall utilization of LNG regasification

capacity during year 2016-17 was around 75%. LNG Terminals are under

construction/implementation stage across India and once functional would substantially

increase the regasification capacity in the country.

With natural gas being the cleanest fossil fuel, LNG is the fuel of choice for the project. The

main advantages in the use of LNG are listed below:

• Lower carbon footprint on substitution of liquid fuels;

• LNG sourcing at competitive price and on customized terms;

• Cheaper and Cleaner source of energy leading growth and revival of gas based

industries;

• Reduced cost of industrial protection;


7

• Accelerated socio-economic development and Supplement to depleting economic

growth;

• Help in CGD networks in major towns and cities, mainly benefitting vehicular

transport &households

At present, there is a strong imbalance within the country with regard to consumption of

natural gas. An affiliate of BCPL has carried out gas demand assessment for the following key

sectors:

a) Large Industrial users

• Power Plants

• Fertilizer Plants

• Refineries and Petrochemicals

• Iron and Steel

• Cement

b) CGD Business

• Residential

• Transport

• Small industrial and commercial

Natural gas demand supply scenario of the nation over last decade has been depicted below in

figure 1. Natural gas consumption of the country is met through domestic production (net of

auxiliary consumption of producing companies and natural gas flared) and LNG imported from

various countries. Of late, due to the decrease in the domestic production of Natural Gas in

India, the shortfall created was satisfied through import of LNG. During 2016-17 out of total

NG consumption in the country 50% of volume was imported LNG.


8

Fig 1: NG Consumption – Supply scenario – India (in BCM)

During year 2016-17, total natural gas consumption in the country was around 49.7 BCM.

Maximum use of Natural Gas was in fertilizers sector (30%) followed by power generation

(23%) and 14% natural gas was used for city or local distribution networks. Sector-wise

distribution of natural gas off-take has been depicted in below figure 2.

Fig 2: Sector wise Natural Gas Take off (2016-17)

Sectors identified for domestic gas allocation are listed here:

• Gas based fertilizer (urea) plants

• LPG Plants

• Power Plant Supplying to Grid / state utilities at regulated rates under PPA

• CGD network for domestic and transport sectors

• Steel, Refineries and Petrochemicals for feedstock purpose

Fertilizer Industry; 30%

Power; 23% City or Local Natural Gas Distribution

Network; 14%

Refinery; 11%

Petrochemical; 8%

Miscellaneous; 7%

Sponge Iron; 2%

Others; 4%


9

• CGD network for Commercial and Industrial consumers

• Any other customers for captive & merchant power, feedstock or fuel purpose.

Details of existing and proposed LNG terminals are given as table 1.

Table -1: LNG Terminal Capacity (in MMTPA)

Sr.

No. Location Owner

Capacity

(MMTPA) Status

Existing

1. Dahej, Gujarat Petronet LNG 100% 15.0 Operating

2. Hazira, Gujarat Shell 74%; TOTAL 26% 5.0 Operating

3. Kochi, Tamil Nadu Petronet LNG 100% 5.0 Operating

4. Dabhol, Maharashtra

GAIL 31.52%; NTPC 31.52%;

Indian financial institutions 20.28%;

MSEB Holding Co. 16.68%

1.7

Operating

(in phase-1 without break water - to be

increased to 5 MMTPA)

5. Mundra, Gujarat GSPC – Adani 5.0 Ready for commissioning

Total Existing Capacity 31.7

Total Existing Capacity

(BCM)* 43.1

Planning / Under Construction Stage

1. Pipavav (Jafrabad), Gujarat Swan Energy 5.0

Planning / Advance stage of Financial

closure. Letter of Intent has been issued

to the EPC, Contractor for the topside

during May 2017. – Annual Report of

Swan Energy, 2016-17

2. Jaigarh, Maharashtra H-Energy – Phase I 4.0

Under Construction, Expected

completion of construction by Mid of

year 2018

3. Ennore, Tamil Nadu IOCL 5.0 Under Construction

4. Chhara, Gujarat HPCL Shapoorji Energy Ltd. 5.0 Under Construction

Total Under Construction /

Planning MTPA 19.0

Total Under Construction /

Planning BCM 25.8

Other Proposed LNG Terminals

1. Dhamra, Orissa Adani – IOCL 5.0 Planning stage

2. Kakinada, Andhra Pradesh GAIL 5.0 Planning

3. Jaigarh, Maharashtra H-Energy – Phase II 4.0 Planning, would be undertaken after

completion of Phase I

4. Digha, West Bengal H-Energy 4.0 Planning, expected commissioning by

Q42020

5. Nana Layja in Kutch, Gujarat

GIMPCL (Gujarat Integrated Maritime

Complex Pvt Ltd, a subsidiary of IL&FS

Maritime Infrastructure Company Ltd.)

5.0 Proposed

6. Krishnapatnam Port KEI-ROSS Petroleum and Energy Private Ltd.

(LNG Bharat) 5.0 Proposed

7. Kakinada Deep Water Port Krishna Godavari LNG Terminal Private

Limited 7.2 Proposed

8. Kakinada Deep Water Port GMR Holdings Private Limited 1.8 Environment clearance received

Total Proposed Capacity MTPA 37.0

Total Proposed Capacity BCM 50.3

http://www.livemint.com/Industry/vAK6Q4pYClAmjvG5nDR6jJ/Adani-to-help-start-up-LNG-import-terminal-at-Mundra.html

http://www.livemint.com/Companies/2i0xUtdVg0rlcieVMt42nO/Hiranandani-energy-arm-HEnergy-may-sell-up-to-20-stake-in.html



https://economictimes.indiatimes.com/industry/energy/oil-gas/petronet-eyes-26-per-cent-stake-in-iocs-lng-terminal-at-ennore/articleshow/60006188.cms

https://www.thehindubusinessline.com/economy/logistics/shapoorji-pallonji-group-bids-for-lng-regasification-terminal-project-at-mumbai-port/article9816331.ece

https://economictimes.indiatimes.com/industry/energy/oil-gas/adani-plans-to-build-5-mtpa-lng-terminal-in-east-india/articleshow/62820729.cms

https://www.thehindubusinessline.com/companies/shell-engie-exit-kakinada-lng-project/article9710528.ece

http://www.henergy.com/east-coast-project/

http://www.henergy.com/east-coast-project/

http://www.ilfsmaritime.com/nana_layja_integrated_maritime_complex.php

http://www.business-standard.com/article/economy-policy/krishnapatnam-port-to-expand-bouquet-build-liquid-bulk-cargo-lng-terminal-118011600596_1.html

http://www.thehindubusinessline.com/economy/logistics/krishna-godavari-floating-lng-terminal-gets-inprinciple-nod/article8928203.ece

http://www.thehindubusinessline.com/economy/logistics/krishna-godavari-floating-lng-terminal-gets-inprinciple-nod/article8928203.ece

https://www.thehindubusinessline.com/economy/logistics/krishna-godavari-floating-lng-terminal-gets-inprinciple-nod/article8928203.ece

https://www.thehindubusinessline.com/economy/logistics/krishna-godavari-floating-lng-terminal-gets-inprinciple-nod/article8928203.ece


10

The energy security of a nation has an important role to play towards its growth. The demand

for energy in developing nations continues to soar at an alarming rate with India being no

exception to this. The primary energy consumption of India in 2015 was about 5% higher than

2014. The GOI (Government of India) has recently launched a #Gas4India campaign where it

focuses to promote the use of Natural gas all over the country by conducting various social

media engagement as well as hyper-local offline events and increase the total share of Natural

gas in country’s energy basket from 7% to 15% by year 2025.

However, the share of natural gas in the energy pool is likely to increase over the coming

years, considering India’s relentless efforts in reducing emissions and cost effectiveness of

natural gas vis-à-vis other fuels. The recent policy reforms for natural gas usage in power and

fertilizer sector clearly indicate the nation’s strong desire to move towards a gas based

economy. Keeping in mind the lack of availability of Natural Gas in the eastern part of India,

there is a strong need to develop necessary Infrastructure in order to cater the natural gas

demand. Considering the attractiveness of the location, huge untapped gas demand of nearby

industries and low LNG prices, there is a strong case for development of a LNG regasification

terminal at Kukrahati.

2.3. DEMAND – SUPPLY GAP

The increase in the usage of natural gas as fuel, feedstock and other industrial and domestic

applications is highly dependent on creation of integrated natural gas infrastructure including

LNG regasification terminals, CGD networks, cross-country pipelines etc. The region wise

distribution of natural gas pipeline infrastructure is presented in the table below:


11

Table – 2: Region wise share in gas consumption and pipeline activity

Region Approx. %of

Total gas P/L

network

% of

consumption

States with infrastructure

and consuming gas

States lacking or having

inadequate pipeline

infrastructure

Western 40% 53% Gujarat, Maharashtra

Northern 20% 26% Delhi, UP, Haryana,

Rajasthan

Punjab, J&K, Himachal

Pradesh, Uttarakhand

Central 13% 3% Madhya Pradesh Chhattisgarh

Southern 16% 14% Tamil Nadu, Andhra

Pradesh

Kerala, Karnataka

Eastern 0% NIL - Bihar, West Bengal,

Jharkhand, Orissa

North

Eastern

10% 4% Assam, Tripura Meghalaya, Sikkim, Arunachal

Pradesh, Mizoram, Manipur,

Nagaland

As it is evident from the details mentioned in Table-2, the pipeline infrastructure is highly

skewed towards northern and western parts of the country and the state of West Bengal is

deprived of natural gas infrastructure. The gap between supply and demand warrants a need

to create infrastructure for gas supply from external resources particularly from the eastern

coast of India to cater to the need of the region.

2.4. IMPORTS vs. INDIGENOUS PRODUCTION

LNG will be imported from suitable source through LNG carriers and this imported LNG will be

regasified at the project site and transported to customers through evacuation pipelines. There

is no indigenous production at the site.

2.5. EXPORT POSSIBILITY

Export possibility of Gas is high, considering the need emanating from the neighboring country

of Bangladesh. BCPL, through its proposed LNG terminal at Kukrahati, intends to cater to the

demand of Western Bangladesh.


12

2.6. DOMESTIC / EXPORT MARKETS

DOMESTIC MARKET:

Overall gas demand in West Bengal is expected to increase from 5.19 MMSCMD in 2020 to

18.17 MMSCMD in 2040 at CAGR of about 5%. Consumers in the catchment area of West

Bengal are mainly categorized in two major heads viz.

a) Major Industrial Customers

The major industrial units have been broadly categorized as per the usage pattern, i.e.

feedstock, process and heating. The sectors considered were the following:

Feedstock

• Fertilizer

• Refinery & Petrochemical

Process and Heating

• Aluminum

• Iron & Steel

b) Potential CGD Networks

Expected consumption for the total demand of CGD sector has been forecasted into following

subsectors:

• Residential

• Industrial & Commercial

• Transportation

Gas Demand summary (in MMSCMD) for consumers by 2020-21 with distance

ranging from 0-25km from the project site at project site is shown in below table:


13

Table 3: Gas Demand Summary in India

Distance from BCPL project site (in kms)

Location Details

Total Demand for Natural Gas in 2020-21 (MMSCMD)

10.0

East Medinipur

0.44

3.75

15.0 0.10

20.0

24-Paraganas 0.06

Hooghly 0.09

Demand from GCGSCL (CGD) 0.75

Total Estimated Demand in West Bengal by 2020-21 5.19

EXPORT MARKET:

• Overall gas demand in Bangladesh is expected to increase from 75 MMSCMD in 2015 to

136 MMSCMD in 2030 at CAGR of 4%

• Maximum demand is likely to be from the power sector followed by the industrial segment

and then domestic & commercial segments. Gas consumption of power sector is expected

to increase from 46 MMSCMD in 2015 to 82 MMSCMD in2030

• Present gas reserves, if fully exploited can meet the gas demand at best up-to 2025 with a

demand growth rate of 5% per year

• Gas shortage and mushrooming of liquid-fuel plants provides thrust for greater fuel

diversification – scope for LNG based plants

• Most of the Bangladesh’s pipeline network is concentrated in the more populated and

developed eastern zone of the country. The present infrastructure coverage is inadequate

to service key market areas of the country, as most of the supply points are in north-

eastern and central regions, while the delivery points are located in south and west

• Expansion of pipeline infrastructure and import of RLNG will ease the pressure on gas

deficit. Better connectivity to gas grid and availability of RLNG will ensure stranded power

and fertilizer plants utilize their capacity


14

• The sector wise estimated demand (in the West Bengal & Bangladesh) by 2040 (near the

proposed pipeline) has been provided below:

Table 4: Sector wise demand in West Bengal and Bangladesh

Demand in

2040

Fertilizer Power Iron &

Steel

Petrochemical

& Refinery

CGD Estimated

Demand

In

MSCMD

8.44 7.20 3.10 8.35 5.86 32.95

In

MMTPA

2.34 2.00 0.86 2.32 1.63 9.15

2.7. EMPLOYMENT GENERATION (DIRECT AND INDIRECT)

During the construction period, approx. 500 skilled/semi-skilled/unskilled workers will be

engaged by various contractors on temporary basis. During the operation phase,

approximately 50 skilled persons of Indian/Foreign will be stationed by the O&M Contractor

on the FSU/FSRU. At the site, approx. 50-100 skilled/semi-skilled persons of Indian/Foreign

origin would be required to operate the jetty and onshore facility. Further, natural gas, being a

cleaner fuel, will replace some of FO, Naphtha and Diesel requirements as a fuel source.

Industries dependent on LNG will develop in eastern India generating additional employment

in the future.


15

3. PROJECT DESCRIPTION

3.1. TYPE OF PROJECT

The proposed LNG Storage and Regasification project at Kukrahati shall have a maximum

capacity of 5 MMTPA.

The project consists of ~600m long jetty in the Hooghly River to moor a FSU/ FSRU/ Shuttle

vessels. LNG shall be stored either in the tanks provided on board the FSRU/FSU or in tanks

built on land. The received LNG shall be regasified through vaporizers provided either on the

Jetty (Jetty Regasification System)/ Land (Land based regasification system) or onboard the

FSRU. The R-LNG thus produced shall be delivered to the customers through suitable onshore

evacuation pipelines.

Also, a truck loading facility shall be set up to transport LNG to the customers by Cryogenic

Road Tankers. LNG shall also be reloaded in small vessels for bunkering of other vessels. BCPL

has appointed M/s ERM India Private limited for conducting Environment baseline

monitoring studies for Kukrahati site. The basic engineering studies necessary for the project

including jetty and onshore facilities are currently in progress. BCPL plans to commission this

project by Q2, 2021.

3.2. SITE LOCATION

The proposed site is located at Matiramchak mouza, Kukrahati, Purba Medinipur district,

West Bengal. Project location is shown in below figure 3. The project site has a water front of

900m along the Hooghly River. The latitude and longitude of project site condition is as

follows:

Latitude: 22°11'21.20"N,

Longitude: 88° 6'34.64"E


16

Fig 3: Project Location

BCPL has initially carried out reconnaissance for various alternate sites for setting up LNG

regasification terminal. Details of alternate sites are provided in section 3.3 below. The

selected site at Kukrahati has been selected based on the following advantages:

- Easy accessibility to Navigational channel of KoPT

- Availability of sufficient fallow land where no agriculture or Commercial activity

- The identified parcel of land has already been earmarked for industrial use

- Sufficient waterfront area

- Availability of local manpower in the immediate vicinity

- Availability of Construction Materials such as Sand, bricks, Steel etc. from the local markets.


17

-

3.3. DETAILS OF ALTERNATE SITES

BCPL had also identified few other sites for construction of jetty to berth FSRU/FSU within a

radius of 25km from Haldia in order to cater to the demand in the area. Approximate location

details of a few of the land sites are as follows:

Site 1: Latitude: 22° 4'21.99"N, Longitude: 88°14'8.13"E

Site 2: Latitude: 22° 1'11.70"N, Longitude: 88°12'50.69"E

Site 3: Latitude: 22°10'23.92"N, Longitude: 88°11'57.67"E

Site 4: Latitude: 22°12'15.87"N, Longitude: 88° 8'22.31"E

Site 5: Latitude: 22°11'21.20"N, Longitude: 88° 6'34.64"E

The above sites had been identified for the proposed project. However, the proposed site at

Kukrahati (Site 5) located at Latitude: 22°11'21.20"N, Longitude: 88° 6'34.64"E has been found

to be the most suitable for the project. The site will be used for constructing a jetty structure

to berth FSU/FSRU and LNG Shuttle Vessels for the project. BCPL is committed to identify

solutions that minimize potential impact on the environment and communities.

3.4. SIZE OF OPERATION

BCPL intends to develop an LNG project at the proposed site at Kukrahati. Based upon future

requirements, suitable additions or modifications may be done in terms of building additional

infrastructure and miscellaneous facilities. The terminal is envisaged to handle 0.3 to 3.0

MMTPA of LNG/RLNG during the first 5-6 years of operation. It is also envisaged that the

demand may ramp up to 3.0 – 5.0 MMTPA after the initial 5 years of operation.

During this operational period, LNG vessels including FSU/FSRU/Shuttle Vessels shall berth at

the proposed jetty. Shuttle vessels of about 10,000 m3 to 40,000 m3 m3 size will bring the

LNG for regasification at suitable intervals based on throughput. Multiple pipelines are

envisaged to emanate from the site to deliver Re-gasified LNG (R-LNG) to the end users. Also,

Trestle


18

a truck loading facility shall be constructed to deliver LNG to the customers in West Bengal

and Bangladesh. LNG shall also be reloaded in small vessels for bunkering of other vessels

and delivering gas further upstream the river along Inland Waterway 1.

3.5. PROCESS DETAILS

Typical process flow diagram for LNG regasification plant.

Fig 4: Process Flow diagram of LNG regasification

The total process has three distinct components:

A) Storage of LNG

B) Vaporization of LNG

C) Loading of LNG Trucks

BCPL is evaluating multiple options for each component as follows:

A) Storage of LNG

i) Floating Storage (FSU/FSRU of 40,000 m3 capacity)

ii) On land storage ( 2 x 20,000 m3 tanks) or (8 x 5000 m3 tanks)


19

B) Vaporization of LNG

i) Intermediate Fluid (Propane/Water mixture or Glycol/Water mixture) Vaporizer

onboard the FSRU ( 3 x 250 mmscfd)

ii) Intermediate Fluid (Propane/Water mixture or Glycol/Water mixture) Vaporizer on the

Jetty ( 3 x 250 mmscfd)

iii) Intermediate Fluid (Propane/Water mixture or Glycol/Water mixture) Vaporizer on

land ( 3 x 250 mmscfd)

iv) Ambient Air Vaporizer on land (750 mmscfd) – with or without fans / supplemental

heating system

C) Evacuation of LNG/RLNG

i) Onshore pipelines for RLNG

ii) Cryogenic trucks for LNG - on land storage of 3 x 2000 m3 capacity and 18 truck loading

bays with future expansion plan to deliver 2 MMTPA of LNG

After considering all the above components, the following options were found to be

workable.


20

Option 1 – FSRU

Mode of receiving LNG Shuttle vessel 30,000 m3 storage capacity

Storage of LNG Onboard the FSRU 40,000 m3 storage capacity

Vaporization System Open loop Intermediate Fluid

Vaporizer system using sea/river

water onboard the FSRU

3 x 250 MMSCFD

Evacuation of LNG Cryogenic trucks - 3 x 2000 m3 storage

capacity

- 18 truck loading bays

Evacuation of RLNG Onshore pipelines TBD

Fig 5: FSRU option


21

Option 2 – FSU+ Jetty Regasification Unit


Storage of LNG Onboard the FSU 40,000 m3 storage capacity



water on the Jetty

3 x 250 MMSCFD


capacity



Fig 6: FSU + JRU option


22

Option 3 – FSU + Land based Regasification Unit (LRU) – IFV





water on the land

3 x 250 MMSCFD


capacity



Fig 7: FSU + LRU (IFV)


23

Option 4 – FSU + Land based Regasification Unit (LRU) - AAV



Vaporization System Ambient Air Vaporizer (AAV) on the

land

750 mmscfd with/without

trim heating


capacity



Fig 8: FSU + LRU (AAV)


24

Option 5 – On land storage + Ambient Air Vaporizer (AAV)

Mode of receiving LNG Shuttle vessels 2 x 30,000 m3 storage capacity

Storage of LNG On shore tanks 2 x 20,000 m3 storage capacity

or 8x 5000 m3 storage capacity

Vaporization System Ambient Air Vaporizer 750 mmscfd with/without

trim heating


capacity


with future expansion


Fig 9: On land storage + AAV

BCPL shall analyze each of the above options in detail during the Basic Engineering Stage and

shall finalize the most feasible option. BCPL shall endeavor to select an option which shall have

the least detrimental impact on the environment.


25

3.6. PROJECT FACILITIES

Project facilities to be developed at the regasification terminal will primarily include the

following components:

3.6.1. JETTY

BCPL plans to construct a jetty in the Hooghly river at Matiram Chak to accommodate an

FSU/FSRU/Incoming Shuttle vessel. The FSRU/FSU shall receive LNG from LNG Shuttle vessel

of 30,000 m3. The jetty shall have facilities for handling LNG such as marine unloading arms,

cryogenic pipelines etc. The jetty shall also have means for mooring the FSU/FSRU/incoming

shuttle vessel. Additional equipment and safety features shall be installed based on risk

assessment studies. The jetty would normally be located at a depth suitable to moor the

FSRU/FSU/LNG Shuttle Vessel to the jetty. The prevailing depths near the project site in the

river channel is >10m and there may not be any dredging required. However, if the jetty is to

be located at shallower depths < 7m, based on recommendation from the Kolkata Port Trust

(KoPT) dredging would be required and dredge material would be safely disposed as per

existing practices of KoPT

A Trestle shall connect the jetty to the project site. Both LNG and R-LNG Unloading Arms and

pipelines shall be mounted on the trestle. The Vaporizers for LNG regasification shall be open

loop with water and Glycol as Intermediate Fluids and shall be installed either on the jetty or

on the project site.

3.6.2. MARINE UNLOADING ARMS

Marine unloading arms will be designed based on the LNG transfer rate of LNG Vessels.

Suitable numbers of Liquid, vapour and hybrid loading / unloading arms manifolds would be

arranged on both starboard and port side of the FSRU/FSU/LNG Shuttle vessel. However, the

configuration and design of marine unloading arms shall be determined based on detailed

engineering.

3.6.3. ONSHORE FACILITIES

The terminal will have various onshore facilities for smooth operation of the project. A

probable list of main equipment at the facility includes:

• Control room


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• Pressure Reduction Facilities

• cold vent system/flare

• filters

• compression skid

• Pig launcher/receiver

• power generation system

• ESD valves station

• Metering skid

• Valves station

• Firefighting system

• Modular Vaporizers on land / on Jetty

• Boil of gas Compressor

• EXPORT Gas Compressor

• LP Section drum

• Recondenser / Reliquefaction

• System to handle Intermediate fluid

• Nitrogen generation plant

• Instrument air plant

• Sodium hypochlorite / required bioside dosing system

• Pumps to handle Sea water, HP LNG, LP LNG

• truck loading bays

• 2 x 20,000 m3 or 8 x 5000 m3 LNG onshore Storage tanks

• 3 x 2000 cu.m storage tanks for LNG truck loading, diesel for Gensets

• Knock out drum and flare

• Underground and above ground piping system


27

• Diesel/Gas Gen-sets

• UPS

• Security room

• SCADA

• Driver’s Room

• Pumps

• Maintenance workshop – Repairs

• Canteen and Guest house

• Store and storage yard for

- Equipment

- Pipes, valves, fittings

- Spares for LNG facility

- Spares for Jetty operation and Maintenance

- Instrumentation and electrical spares

- Insurance spares

Headers for evacuation pipeline(s), emergency response systems, fire protection systems,

provision of utilities shall also be included in the facilities at the project site.

3.6.4. ONSHORE STORAGE TANKS

The LNG import/receiving marine facilities are essential part of an onshore based LNG

terminal, LNG unloading from Shuttle vessel ship shall be accomplished via hard-piped

cryogenic liquid unloading arms located on the jetty platform, transferred to the LNG storage

tanks at the terminal through cryogenic pipelines located on the trestles running to the shore.

Vapour displaced from the land-based storage tanks whilst the ship is unloading is also

returned to the ship via a vapour return arm. The Boil off Gas (BOG) from the LNG tanks shall

be compressed and routed to a recondenser where the BOG vapours are condensed with LNG

from the storage tank at about 5-10 bar pressure to achieve total condensation of the BOG.

The LNG is pressurised by the High Pressure (HP) pumps upto send-out pressure and then


28

vaporised in the heat exchanger at high pressure. Both the pipes and LNG storage tanks are

insulated to maintain the low temperature. LNG storage tanks are designed and constructed

using special materials to contain the cryogenic liquid. LNG storage tank dimensions and

specifications shall be finalized during the detailed engineering stage.

3.6.5. OFF-LOADING SYSTEM

LNG offloading shall be carried out by hard/soft unloading arms. Once the LNG Shuttle vessel

is berthed alongside the FSU/FSRU structure, the LNG unloading arms are moved and

connected to the manifold flange. The pressure of the LNG Shuttle vessel and that of the

FSU/FSRU/Onshore storage tanks shall be balanced via the vapour return line with a slight

differential pressure in order to enhance vapour return. Cool-down of unloading arms shall

then be started from the LNG Shuttle vessel and from the FSU/FSRU. Cool-down shall be

carried out by pumping a small flow of LNG into the arms using the LNG Shuttle vessel spray

pumps. The Cargo pumps shall be started and the LNG transfer rate gradually increased until

the design-loading rate is reached. LNG shall be loaded through the manifolds and transferred

simultaneously into all the FSU/FSRU/On land storage tanks.

During the loading operation, sufficient natural gas shall be returned to the LNG Shuttle vessel

via the vapour return line and vapour arm in order to maintain the LNG Shuttle Vessel storage

tank pressure. In case the differential pressure is not sufficient to ensure the natural gas flow,

High Duty (HD) compressors shall be employed. When the loading operation is complete,

prior to disconnection, the arms shall be emptied and purged using nitrogen. The onboard

nitrogen generators shall be mainly used for this scope. When loading is not in progress, the

loading lines shall be kept in cryogenic conditions by circulating a small amount of LNG in the

lines. This shall be achieved by pumping LNG to the loading lines using the Spray Pumps and

returning it to the LNG storage tanks.

3.6.6. LNG STORAGE

LNG will be stored in suitably sized cargo tanks of FSU/FSRU/On land storage tanks provided

at the project site. Each cargo storage tank shall be equipped with block valves on the filling

lines, which allow isolating the tank in case of emergency. Moreover, in case of failure of the

tank pressure control system, each tank shall be protected against over pressure by

independent safety valves discharging directly to the atmosphere via a dedicated vent mast.

Tanks will be provided with one radar type level instrument to monitor the level and give high


29

and low level alarms. In addition, an independent high-level switch will be fitted to initiate the

shutdown of the LNG Shuttle Vessel loading operation to protect the tank from overfilling in

case all other preventive actions fail. Each tank will be also supplied with a Level Temperature

Density (LTD) measurement instrument, which allows measuring of liquid level, tank

temperature profile and tank density profile. This instrument will be used to monitor tank

stratification and as a backup for the radar level instrument. Cargo tanks will be equipped

with submerged electric LNG In-tank pumps used to lift LNG from storage tanks to the

regasification plant. The cooling of the electric motor and bearings and bearings lubrication is

ensured by pumped LNG. The start/stop of each LNG in-tank pump will be controlled by the

operator who shall ensure that enough pumps are in operation to fulfill the gas send out flow

rate.

Each pump discharge will be equipped with:

A minimum flow recirculation, which ensures that the pumps never operate below

their minimum flow. The minimum flow recirculation will also be used for pump start-

up.

A vent to tank. During pump start-up sequence the vent will be opened to allow

venting the gas contained in the pump well. The vent opening will be controlled by a

timer. After an adjustable time, the vent will close.

Tanks will be equipped with spray pumps. Each pump discharge will be equipped with a

control valve, which enables to control the pump electrical current. Moreover, a return line to

tank with an additional control valve will be provided in order to control the spray nozzles in

let pressure.

3.6.7. LNG REGASIFICATION

a) IFV

Regasification system shall be river water and glycol based IFVs (Intermediate Fluid

Vaporizers). After heat exchange the water will be discharged back to the river at

temperature lower than the ambient. Water from the vaporization system will be discharged

after maintaining an acceptable temperature gradient as per World Bank Guidelines. Ballast

water will be discharged at ambient temperature. Bilge water will be treated onboard the

FSRU/FSU before discharge. The sewage generated will be treated before discharge.


30

The LNG regasification system will be provided with either shell and tube vaporizer or by

water based Intermediate Fluid Vaporizers (IFVs) provided on jetty/FSRU/on land. High-

pressure LNG booster pumps will be provided in the regasification area for feeding LNG to the

IFVs to the expected send out pressure. The LNG Booster Pumps will suck LNG from the Re-

condenser. Each booster pump will be designed in order to guarantee the maximum send-out

flow rate and the best flexibility and maintainability without production interruption of

limitation.

Fig 10: Example of IFV

Each pump will be equipped with a dedicated recirculating flow line to the Re-condenser to

prevent pump operation below minimum flow. Intermediate Fluid Vaporizers will be used to

vaporize the send-out LNG. Two examples of IFVs are presented above in figure 10.

IFVs will be counter-current heat exchanger and will use water as a heat source and propane

or water glycol as an intermediate heating medium between water and LNG. The

intermediate fluid in the IFVs will be circulated in closed loop with no requirement for

makeup or pumping during normal operation. In case of over pressure in the propane/water

glycol vaporizer, a safety relief valve will be provided which discharges in a dedicated propane

vent header. The LNG flow rate to the IFVs will be under flow control. The valve will be

actuated by the ESD. Propane will be stored in steel pressure cylinders, while glycol in steel

tanks.

b) Ambient Air Vaporizer

LNG Ambient air vaporizers (AAV) are relatively uncomplicated heat exchangers which

vaporize liquefied gas by using heat absorbed from the ambient air. Due to this simple

principle of operation these vaporizers do not require external power. LNG passes through a


31

number of interconnected tubes in various series and parallel paths. Ambient air vaporizers

are in operation in a wide range of applications throughout the industry.

An important issue related to AAV is the necessity of having a regeneration period (typically

after 8 hrs.) for defrosting and hence are normally used for peak shaving. For such reason, to

guarantee continuous operation, spare set shall be considered. AAVs are available for

different pressure rates. However typical pressure rating for all-aluminum exchangers is 40

barg. Higher rating is available mainly for small capacities.

Fig 11: Example of AAV

Fig 12: Process Flow Diagram


32

In AAVs, air can be forced by fans to increase heat transfer rates and minimize required plot

area. Disposal vaporizers use a jet of air to vaporize off-spec oxygen, nitrogen or argon and

return it to the atmosphere as a gas. Ambient air vaporizers can be used to vaporize nitrogen,

oxygen, argon, CO2, ammonia, chlorine, LNG, ethylene and all other cryogens and liquefied

gases. A natural draft vaporizer matrix is enclosed in an aluminum shroud with a fan(s)

mounted on top. Air is forced down through the duct, increasing heat transfer. Controls

include a motor starter and an auto-start thermoswitch. Dual defrostable units are available

for continuous operation.

The performance of ambient air vaporizers, which use the relative “heat” of the atmosphere

to derive the energy necessary for the vaporization of the liquid cryogen, is subject to many

factors. These include flow rate, duty cycle, ambient temperature, relative humidity, freeze

period, altitude, wind, solar radiation, operating pressure and proximity to adjacent

structures. Performance is based on mean ambient conditions of 700F (210C) and 70%

relative humidity. Special conditions may vary considerably for a particular application,

thereby affecting performance. Ambient vaporizers represent the most cost effective

equipment to vaporize or re-gasify liquid cryogens. Once installed there are no operational or

Maintenance costs. All that is required is regular defrosting of the heat transfer elements.

3.6.8. BOG HANDLING AND FUEL GAS SYSTEM

The boil off gas produced both by natural cargo heating and by operations will be handled by

the BOG handling system, which is made up of the following main equipment:

• LD Compressors;

• HD Compressors;

• Scrubber and Heater.

The BOG handling system will manage the BOG production in two ways:

• Providing fuel gas to the fuel gas header;

• Sending the BOG to the Re-condenser for re-condensation.

The main source of fuel gas is the boil off that is compressed by LD Compressor up to the

required pressure.


33

3.6.9. WATER SYSTEM

A water system will be provided to supply the required water to the LNG Vaporizers for

vaporization. Water system is made up of:

• Water intakes;

• Water pumps;

• Water filters installed upstream water pumps provided for protecting pumps;

• water filters provided for protecting LNG Vaporizers

The water will pass through water filters and will be pumped by the water pumps to the LNG

Vaporizers. Water filters will be provided on discharge header to protect LNG Vaporizers.

Water will then be routed overboard through gooseneck and, then, to the water discharge

line. Almost 5000 m3/ hr of water shall be required for 1 MMTPA LNG to vaporize. For the

maximum capacity of annual throughput of 5MMTPA, total 25,000 m3 / hr of water would be

required for regasification.

3.6.10. VENTING SYSTEM

The FSRU/FSU shall be constructed with no venting philosophy. However, the FSRU/FSU will

have the venting system which in case of emergency will aim to discharge any flammable

vapour release to atmosphere at safe location, thus minimizing any potential risk to involved

personnel. For the onshore facility, it is proposed to install cold flare venting system. This

venting system shall be used for normal operations and maintenance of the onshore facility,

including but not limited to pipelines, vaporizers, metering system etc. All the venting outlets

in the onshore facility will be connected to the common venting point.

3.6.11. NITROGEN SYSTEM

A nitrogen system will be available for the following types of services:

Purging of unloading arms: vapour and liquid unloading arms shall be purged after any

loading;

Intermittent services (tank barriers, sealing system between compressors and relevant

motors, other seals, vent system purging);

Continuous (essential) services (tank barriers, purging of the vent mast (first purge)


34

and of unloading arms, continuous services).

The system will be made up of:

Two redundant nitrogen generation packages;

A buffer tank;

A nitrogen distribution system

3.6.12. EVACUATION PIPELINE SYSTEM

3.6.12.1. HORIZONTAL DIRECTIONAL DRILLING

Horizontal Direction Drilling method will be used for laying underground pipeline

across the river Hooghly

Horizontal directional drilling (HDD) is a steerable trenchless method of installing

underground pipelines in a shallow arc along a prescribed bore path by using a

surface-launched drilling rig, with minimal impact on the surrounding area. HDD is

used when trenching or excavating or digging is not practical. In this methodology the

drilling rig is placed on one bank of the river (Kukrahati side) and the pipe to be

installed across river crossing would be stringed at the other end of the bank near

Mukandapur, left side of Raichak. On making requisite hole beneath the scour depth

of the river the pipe would be pulled in the designated profile.

Installation of a pipeline by HDD is generally accomplished in three stages: (1) Pilot

hole drilling, (2) Boring/reaming operation of the pilot hole, (3) Pulling the pipeline in

the reamed hole

River crossing by R-LNG pipeline shall be at least 5.0 m below the riverbed and shall be

done using Horizontal Directional Drilling Method. This process will not impact any

road/rail/river traffic during construction or operation.

The main advantages in carrying out pipeline installation by horizontal directional

drilling methodology are (1) it will involve installation of Three Layer Polyethylene

(3LPE) coated pipes. No measures are required to be taken for ensuring anti-buoyancy

of the pipes such as concrete coating. (2) It is comparatively more environment

friendly. Requirement for cutting of mangroves or any other environment friendly

tress across the river will not be required. (3) It will pass well below the river bed


35

(scour depth) such that no impact on river water and its flora fauna.

3.6.12.2. DIRECT PIPE METHOD

The Direct Pipe method combines the advantages of the established laying methods of

Microtunnelling and Horizontal Directional Drilling (HDD)

A Microtunnelling machine is mounted in front of the pipeline. To facilitate Tunnel

Boring Machine (TBM) control, two to three angular steel pipes (connection pipes) are

installed between the pipeline and the machine. The Pipe Thruster operates as thrust

unit from the launch pit clamping the pipeline on the outside and pushing the machine

as well as the pipeline into the ground.

This method uses less bentonite. Hence, it is more environmental friendly, using less

Bentonite.

3.7. RAW MATERIAL REQUIRED

Considering the nature of the envisaged project, the primary raw material required will be

LNG, which will be sourced by BCPL from a suitable source. Other miscellaneous raw material

will be sourced locally or from outside sources as per the requirement, depending upon its

availability. Construction materials will be transported to site through existing road network /

water ways along Hooghly river. During operational phase, LNG will be transported using LNG

vessel through Hooghly River to the LNG Storage Tanks situated on land or in the FSU/FSRU.

3.8. RESOURCE OPTIMIZATION

BCPL has charted out a comprehensive roadmap, which shall be meticulously followed in

order to obtain the desired project progress. To this regard, BCPL has plans to expand its

available resources (Human, Machinery and Financial) to achieve Resource Optimization.

3.9. AVAILABILITY OF WATER, ITS SOURCE AND ENERGY REQUIREMENT

River water is abundantly available in the vicinity of the proposed project location. BCPL

intends to utilize these sources responsibly for carrying out operations. Approx. 100 KLD river

water will be required for civil construction work. For Horizontal Directional Drilling, bentonite

mixed with water shall be used as the Floating medium and shall be sourced separately via

road tankers. For Hydrotesting of the pipeline and equipment, approx. 10000 m3 water shall

be required.


36

5,000 m3 / hr of river water would be required for regasification in the initial stage of the

project. When demand ramps up, Maximum of 25,000 m3/hr of river water would be

required for regasification (@5000 m3/hr/1 MMTPA LNG). After meeting the discharge

standards, these waters will be discharged back into the river. Further, 150 m3/hr of

groundwater shall be used for fire water storage system, 2000 m3/hr river water will be

required for auxiliary cooling system and a maximum of 1500 m3/hr river water shall be

required as ballast water. 2-3 KLD groundwater will be required for domestic requirement of

operational workers.

Power requirement during construction phase will be approximately 3 MW and shall be

sourced from the local electricity grid. In case of non-availability of power from the local

grid/disruption of power, temporary DG sets with cumulative capacity of 3 MW shall be used.

The FSRU/FSU shall be self-sufficient and will have on board Power Generation of upto 40

MW, which shall be used to meet all power requirement onboard the FSU/FSRU including

those required for the LNG Handling facility onboard the vessel. In case of the land based tank

and vaporizer option the power requirement would be 20 MW and this power requirement

for the facilities on the jetty and the project site shall be met by the power supplied from the

West Bengal State Electricity Board (WBSEB) or from the power generated onboard the

FSRU/FSU or through gas/diesel backup gensets at project site.

The power requirement for the facilities on the jetty and the project site shall be met by the

power supplied from the West Bengal State Electricity Board (WBSEB) or from the power

generated onboard the FSRU/FSU or through gas/diesel gensets at project site. The boil off

gas from the FSU/FSRU shall be utilized for generation of power in case gas gensets are used.

3.10. WASTE PRODUCTION &DISPOSAL

Onshore Terminal:

The construction phase of the project is the one when most waste is likely to be generated.

EGAS/GASCO Standards shall be followed for waste management. During the construction

phase of the project, approximately 20-25 kg/day and during operational phase 25-30 kg/day

of solid waste will be generated. The MSW will be disposed in the nearby municipal dumping

ground. Some used oil will also be generated from equipment and machineries and DG set.

These will be disposed as per Hazardous and Other Wastes (Management and Transboundary

Movement) Rules 2016.


37

Impacts on local population, land, surface and subsurface waters, air quality, and animal and

plant species, including habitat, shall be considered.

Production and water handling facilities shall be planned to utilize the smallest practical

surface area consistent with safe, prudent, and economic operations. Special care shall be

taken to minimize the possibility of environmental damage due to equipment upsets, spills,

and leaks. Equipment and facilities shall be located and designed to minimize the wastes

generated by operations and maintenance activities. Recyclable products shall be used, where

possible.

Appropriate methods of collecting and recycling or disposing of waste generated during

construction, operation, and maintenance of the facility shall be considered as per the

approved standards in place.

A sound waste management plan is important to protect human health and the environment

and minimize long-term liabilities to the operator. Accordingly, a waste or residual

management plan shall utilize one or all of the options listed below, in order of preference, to

protect human health and the environment.

a) Source Reduction—Minimize or eliminate the volume and/or toxicity of the waste

generated.

b) Recycling—Reclaim or reuse the maximum amount of waste possible.

c) Treatment—Utilize techniques to minimize the amount and the toxicity of waste after

it is generated, thereby minimizing the amount that has to be disposed.

d) Disposal—Employ environmentally sound and approved methods to properly dispose

of generated wastes.

The Waste Management Plan shall specify the types of wastes that will be generated as part

of the construction process as follows:

Aqueous waste (comprising hydro test water, drainage water, untreated sewage

water);

Non-hazardous waste; solid and liquid (domestic refuse, industrial refuse, sewage


38

sludge);

Gaseous wastes (vents, exhausts, fire-fighting agents, refrigerants).

Considerations that shall be evaluated when choosing either an on-site or an off-site

commercial disposal method are as follows:

a) general site review of the topographical and geological features

b) groundwater review to determine the presence of groundwater and aquifers

c) area weather patterns to estimate rainfall and flooding potential

d) general soil conditions

e) natural drainage areas

f) identification of environmentally sensitive conditions

g) air quality

It is pertinent to note that notwithstanding the above, only minor quantities of wastes (mainly

due to maintenance operation) are foreseen. These quantities are negligible if compared to

the ones produced by the FSU/FSRU.

FSRU/FSU

The operation will involve waste production, mainly due to:

• Maintenance operation

• Presence of personnel (medicines, kitchen wastes, etc.)

• Sewage

• Electronic equipment and batteries maintenance

• Packaging


39

Table 5 below includes a list of waste typologies related to the FSRU/FSU operation.

Table 5: Waste Typologies

Waste Waste Physical State

Plastic, papers, glass, wood Solid

Oil sludge (from maintenance operation) Liquid

Paints, varnishes and thinners Liquid

Rags and filter materials Solid

Metals Solid

Medicines Solid

Exhausted vegetable oil and fats, other kitchen

wastes

Liquid/Solid

Sewage Liquid

Oil filters Solid

Waste non contaminated by hydrocarbons Solid

Electronic equipment and batteries Solid

Packages containing hazardous wastes (i.e.: drums

for oil and diesel fuel)

Solid

Not hazardous inorganic wastes Solid

Solvents Liquid

All the waste shall be temporarily stored on the vessel, where proper dedicated areas shall be

identified. Waste will be further sent to an onshore reception facility for final disposal.

Quantities of waste shall be defined during the project development. Related waste will be

handled by a MARPOL compliant Shipboard incinerator capable of handling burning of

allowed waste (Sludge Oil and Solid) generated onboard. Disallowed items as per MARPOL

will be collected in separate bins and landed ashore to shore reception facility.

3.11. SCHEMATIC REPRESENTATION OF THE FACILITY

Refer Fig. 5,6,7,8


40

3.12. NOISE EMISSIONS

Noise emissions are related to:

• FSRU/FSU equipment

• Facilities on Jetty, if any

• On land facilities

For FSRU/FSU, main emission sources include the following:

• Water process pumps

• Water cooling pumps

• Hypochlorite dosing system

• Generation system

• Sanitary discharge pumps

• Booster pumps

• Cooling water unit and Compressors

• Diesel Gensets

• Gas Gensets/Engines

• Fire water Pumps (motor based/ Engine based)

For onshore facilities, in normal operating conditions noise emissions mainly refer to power

generation system and gas compression skid. Sound pressure levels (at 1 m from the source)

can be preliminarily assumed between 75 and 95 dB (A) each. This will be confirmed at later

stage of the project. If necessary, noise reduction measures will be provided.

Noise will be generated during construction from the operation of equipment and machinery.

The machinery used will adhere to national standards and emissions are shall be within

stipulated limits. For FSU/FSRU, main emission sources include River water process pumps;

River water cooling pumps; Hypochlorite dosing system; Power Generation system; Sanitary

discharge pumps; Booster pumps; Cooling water unit and Compressors; Diesel Gensets; Gas

Gensets, engines; Fire water Pumps, HDD Machine. Noise level will be maintained to 75 dB.


41

During operational phase, noise will be generated from pump house and other onshore

facilities. Piling activities are envisaged during construction of jetty, trestle and facilities on

site. Approximately, 75 to 95 dB(A) of noise is expected during piling. ORF sound pressure

levels will be monitored and respect of national regulations in force (“The Noise Pollution

(Regulation and Control) Rules”, 2000) will be guaranteed.

3.13. EMISSION DATA

Project development might involve potential effects on the environment, due to:

• Emissions of pollutants to atmosphere

• Water discharges

• Waste production and

• Noise emissions

Land facilities shall meet the state pollution control board norms. The LNG Regasification

terminal and the FSRU/FSU shall meet the relevant MARPOL and applicable flag

requirements. In detail, the FSRU/FSU will respect environmental limits indicated in the

“International Convention for the Prevention of Pollution from Ships” (MARPOL). MARPOL is

one of the most important international marine environmental conventions. It was designed

to minimize pollution of the seas, including dumping, oil and exhaust pollution. Its stated

object is to preserve the marine environment through the complete elimination of pollution

by oil and other harmful substances and the minimization of accidental discharge of such

substances.

The original MARPOL Convention was signed on 17 February 1973, but did not come into

force. The current Convention is a combination of 1973 Convention and the 1978 Protocol. It

came into force on 2 October 1983. As of 31 December 2005, 136 countries (including India),

representing 98% of the world's shipping tonnage, are parties to the Convention. Following is

an overview on main emission data associated with the project:


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3.13.1. EMISSIONS TO ATMOSPHERE

The Regasification operation will involve the following emissions to atmosphere:

• “Conveyed” emissions due to gas combustion for FSRU/FSU power generation

• “Conveyed” emissions from unit incinerator

• “Fugitive” emissions of Total Organic Compounds (TOC) from FSRU

• Joints and valves (due to LNG receiving system)

• Joints, pumps and compressors (due to LNG regasification and send-out)

• Joints and oil storage tanks (due to energy production)

During normal operating conditions, the FSRU/FSU will be fed by boil-off gas. Exhausts of the

combustion will be represented by NOx and CO emissions. In case dual fuel engines are used,

potential additional emissions of Sulphur oxides and particulate might occur. Emissions will be

conveyed through a stack positioned in the aft part of the FSRU/FSU. The FSU/FSRU unit shall

respect emission limits presented on the Annex VI of the “International Convention for the

Prevention of Pollution from Ships” (Maritime Pollution – MARPOL). With reference to

nitrogen oxides, MARPOL only presents the following maximum NOx emission rates at the

stack for diesel engines:

14.4 g/kWh when rated engine speed n is less than 130rpm

44.0 * n (-0.23) g/kWh when rated engine speed n is 130 or more but less than 2,000

rpm

7.7 g/kWh when rated engine speed n is more than 2,000rpm

With reference to Sulphur oxides and particulate matter emissions, MARPOL states that these

emissions on ships will in general be controlled by setting a limit on the Sulphur content of

marine fuel oils as follows. The Sulphur content of any fuel oil used on board shall not exceed

the following limits:

4.50% m/m prior to 1 January2012

3.50% m/m on and after 1 January2012

0.50% m/m on and after 1 January2020


43

Incinerators installed on board a unit after 1st January 2000 shall meet the requirements

contained in Appendix IV of Annex VI of the MARPOL, presented below:

Percentage of CO2 in combustion chamber:6-12%

CO in flue gas maximum average: 200mg/MJ

Soot number maximum average: Bacharach 3 or Ringelman 1 (20%opacity)

Unburned components in ash residues: maximum 10% by weight

Combustion chamber flue gas outlet temperature range: 850-1,200°C

Additional more limits that are restrictive might be requested by national and local

Authorities during the permitting phase. With reference to fugitive emissions, on the basis of

available information from similar FSRUs, it is possible to estimate a yearly overall TOC

emission equal to 1 ton per year. Maximum NOx concentration for a new gas turbine having a

capacity less than 100 MW is equal to 100 ppm (as per Environmental Protection Rules).

With reference to the onshore receiving facility, the only emissions are related to:

exhausts from vaporizers (NOx and CO), if necessary

exhaust from power generation system

gas emission from the cold vent. These emissions are non-continuous and will only occur

in case of need

emissions of volatile compounds from joints and valves (these emissions are almost

negligible)

A suitable cold/ automatic flare system shall be planned at site during the detail design stage.

All pressure safety valves (PLVS) shall be connected to the flare system for safe disposition.

During construction period, heavy machineries like crane, digging equipment, piling

equipment is likely to give rise to emission from combustion of fossil fuel. During

commissioning and Maintenance activities, some amount of venting of R-LNG would be

required to ensure readiness of plant and equipment.

During normal operation, some emission is expected from operation of heavy/light vehicles.

Vehicles would be used for transportation of materials and shall have valid PUC certificate.

The FSRU/FSU operation will involve the following emissions like from Gas combustion for

during generation of power in the FSRU/FSU/Gas/Diesel Gensets on the site.

During commissioning and Maintenance activities, some amount of venting of R-LNG would

be required to ensure readiness of plant and equipment. Fugitive emissions comprising of


44

grease, lubricating oil, diesel, methane, other combustibles, dust etc. from Joints, mechanical

seals, bearings, flanges, valves, instrumentation tubings, pumps, exchangers, Gensets,

compressors, filters, pig receiver/launchers etc. during handling, storage and transportation

of LNG/R-LNG. Some emission is expected from operation of heavy/light vehicles. Vehicles

would be used for transportation of storage materials/LNG and shall have valid PUC

certificate.

3.13.2. DISCHARGE TO WATER

Water discharges are mainly related to the FSRU/Jetty Regasification Unit (JRU)/Land

Regasification unit (LRU) operation if the regasification is provided on board the FSRU/on

jetty/on land. Potential discharges might be involved by the following:

Regasification; The regasification system shall be water based Intermediate Fluid

Vaporizer (IFVs) with propane or water glycol solution as intermediate fluid. In IFVs

the LNG and water flow in separated streams, both in contact with the same

intermediate fluid. In this type of vaporizer, a double heating process is performed.

Water is primarily used to heat the intermediate fluid. The intermediate fluid then

transfers its heat to the LNG (which vaporizes). After having transferred heat to

the intermediate fluid, water is discharged back to the sea at a temperature lower

than the ambient one; the maximum difference of temperature between the inlet

and the outlet will be equal to 5°C

Power generation system cooling

Ballast; water will be withdrawn and discharged at the same temperature. FSRU

will be provided with 2 to 3 ballast pumps having a total capacity of approximately

2,000m3/h

Sewage: The FSRU/FSU will have a sewage treatment system in order to guarantee

environmental maximum concentration of pollutants and parameters included in

the “International Convention for the Prevention of Pollution From Ships”

(Maritime Pollution –MARPOL)

Bilge

Auxiliary cooling system


45

FSRU/FSU will be provided with a sewage treatment plant meeting the MARPOL

requirements. The sewage will collect:

Grey water

Black water

Black water will be treated; sludge content will be held on-board for transfer to shore

reception facilities. Concentration of pollutants and chemicals at the discharge shall not

exceed limits indicated by the “International Convention for the Prevention of Pollution from

Ships” (Maritime Pollution – MARPOL).

With reference to the onshore receiving facility, it has to be highlighted that, during normal

operation:

The only discharge refers to cooling water for the power generation system and grey

water for the presence of an office; water shall be collected and discharged according to

limits from regulations inforce

The ORF will be provided with a drainage facility for rain water and aseptic tank storage for

handling generated sewage

During construction domestic wastewater will be treated through septic tank and soak pit.

During operational phase, water used for regasification, ballast water, cooling water for

power generation system will be discharged in the river after meeting the discharge standard.

The bilge water, sewage will be treated and then will be discharged into river or in to the

municipal sewage system. Discharge of treated water may not cause significant impact on

receiving surface water body.

The emission from power generation system, flaring and fugitive emissions from storage and

handling of LNG to air during operational phase are not expected to be significant. The risk of

contamination of land or water from such emissions is therefore low to none.


46

4. SITE ANALYSIS

4.1. CONNECTIVITY

Kukrahati is a small town in Medinipur district of West Bengal. It is located around 150km

from Kolkata, and stands on the bank of the Hooghly River, opposite Raichak in South 24

Parganas. It is the gateway to the port and Industrial city of Haldia. There is a ferry service

across the Hooghly between Raichak and Kukrahati and there is good road connectivity

between Kukrahati and Haldia.

4.2. LAND FORM AND LAND OWNERSHIP

The proposed site at Kukrahati is at the bank of river Hooghly. It is an unleveled ground and

has a mild downward slope towards the river. The proposed land for the project site can be

divided into two parts. One part is a vacant land which was earlier allotted for setting up a

shipbuilding yard. However, no construction activity was initiated. The same land is planned

to be taken by BCPL on long term lease. The construction of FSRU/FSU based LNG Terminal

will have the same land use, i.e. industrial activity. The second part of the land is currently

being used as a brick-kiln. The construction of FSRU/FSU based LNG Terminal shall increase

the intensity of land use of this land. There is a small canal in between the two parts of land

proposed for the site. The same shall be retained in an as-is condition and no changes are

proposed.

However, since the project site is on either side of this small canal, required above ground

pipe rack shall be built to transport LNG/R-LNG/other utilities between the two project sites.

Further, required over ground cable tray shall be laid to connect both the plots for electrical /

instrumentation cables.

4.3. TOPOGRAPHY

Detailed Topography map is not available with BCPL. This will be provided at a later stage.

Survey of India’s topography sheet is attached along with Form 1.


47

4.4. EXISITING LAND USE PATTERN

The proposed project site can be divided into two parts. One part is not being used for any

activity (neither agriculture nor non agriculture) currently. The other part is currently being

used as a brick kiln. The project site also does not have any mangroves or endangered plants.

The location of the site is also upstream of the Southern Municipal limit of Diamond Harbour.

4.5. DRAFT AT SITE

All the identified sites have draft restriction of ~7.5m in the channel. However, BCPL is

planning to dredge near the Jetty for safe navigation of LNG Shuttle Vessels inside the channel

and to bring LNG Shuttle Vessels safely for berthing at the jetty.

4.6. EXISTING INFRASTRUCTURE

The proposed project site can be divided into two parts. On one part the land is empty with

no existing infrastructure. In the other part there is an existing brick kiln.

4.7. SOIL CLASSIFICATION

Project site has very soft to medium silt clay / clayey silt with lenses or lamination of silt up to

33.0 m depth below the existing level and extended beyond the termination depth.

4.8. CLIMATIC DATA FROM SECONDARY SOURCES

4.8.1. RAINFALL

Rainfall in Purba Medinipur district occurs primarily during the south-west monsoon months

i.e. June to September and constitutes about 74% of the total annual rainfall. Some rainfall,

mostly as thunder showers, is received in the latter half of the summer season and in

October. Based on the data available in District Statistical Hand Book of Purba Medinipur, the

area receives reasonable rainfall during the wet months of June to September. The highest

average rainfall of 365 mm has been recorded for the month of August, followed by

September (322 mm) and July (298 mm). The total annual rainfall has been 1586mm. The

month wise distribution of mean rainfall during 2010-2014 has been presented in below

figure 13.0


48

Fig 13: Monthly Rainfall Distribution (2010 – 2014)

4.8.2. TEMPERATURE

Interpretation of the secondary data reveals the annual mean maximum and minimum

temperature of the study area to be 36.0°C (April and June) and 8.8°C (January) respectively.

Highest maximum temperatures were recorded during the summer months of March to June

generally varying in the range of 34°C-36°C. The temperature declines during the monsoon

months (July to September). The monthly mean minimum and maximum temperatures are

shown in Fig.

Fig 14: Monthly Temperature Profile (2010-2014)


49

4.8.3. RELATIVE HUMIDITY

There is high humidity all year round as the study area is close to Hooghly and Haldia Rivers.

The mean annual humidity is 74% with July (85%), August (85%) and September (84%) being

the highest humid months.

Figure 15: Mean Relative Humidity in Study Area

4.9. METOCEAN CONDITIONS

4.9.1. WIND

The analysis of wind speed and direction data is considered important for predicting the air

quality impacts based on pollutant dispersion models. The IMD station at Haldia (1971-2000)

recorded highest monthly mean wind speed of 2.8 m/s in May followed by 2.6 m/s in April.

The lowest monthly mean wind speed was recorded as 0.9 m/s in December.

4.9.2. WAVE AND TIDE

The site at Kukrahati in Hooghly River is about 80 KM inside from the Hooghly river mouth at

Bay of Bengal. Therefore, there is no wave at the project site. However, the rise in water level

in Hooghly estuary is due to the tidal influence. The Mean high water level goes up to 4.64 -

5.20 m at Kukrahati during spring tide.

4.9.3. CURRENT

The currents in Hooghly River are due to River flows from Roopnarayan River and upstream of

Hooghly River. The currents are also due to tides from Bay of Bengal.


50

4.9.4. SEA SURFACE TEMPERATURE

Water temperature ranges between 18°C and 33°C, during the year generally without any

appreciable difference between the different regions. The maximum difference between the

surface and bottom temperatures has been found to be 1.5°C.

4.9.5. pH

The range of variation in pH of water in the estuary is generally between 7.9 and 8.4 during

the year.

4.9.6. SALINITY

The most characteristic feature of salinity is the wide range of variation from season to

season. It increases to about 30% in the pre-monsoon season and comes down to almost

fresh water (1.6%) during monsoon months.

4.9.7. SOCIAL INFRASTRUCTURE

Kukrahati bus stand and ferry terminal are located within 2kms from the project site. 7 out of

9 core area villages reported to have at least a primary school within their boundaries, and

secondary and senior secondary schools are located in Barda, Parbatipur.

5. PLANNING BRIEF

5.1. PLANNING CONCEPT

BCPL, through this proposed project, intends to supply LNG and R-LNG to various Customers

in West Bengal and nearby states/Countries. These industries include, but are not limited to

Fertilizers sector, Refining sector, Power Plants and CGDs. Site has already been identified as

Kukrahati in West Bengal. The Project components have also been clearly identified, and their

requirements in lieu of the timelines have also been fixed. The Project Schedule shall be

prepared keeping in mind various factors like timelines for completion of project, project

milestones etc. BCPL also has a system in place for slippage monitoring. Slippages shall be

meticulously monitored and suitable corrective actions shall be performed by BCPL ensuring

that the project timelines are being strictly adhered to.


51

5.2. POPULATION PROJECTION

A detailed demand assessment report shall be prepared by BCPL through a Consultant. This

Report shall contain the Population Projection along with demand figures in the Geographical

area. BCPL shall provide this report along with the figures at a later date.

5.3. LAND USE PLANNING

BCPL intends to use the selected land for setting up an LNG Storage and regasification

terminal. The onshore facilities shall form an integral part of the proposed LNG Storage and

regasification terminal. The facilities on the land may include, but shall not be limited to

storage tanks, pumps, truck loading facility, other miscellaneous like pipes, valves, metering

devices, fire-fighting system etc. Areas for each facility shall be clearly demarcated as per the

applicable standards. Green belt will be developed in the peripheral of the project site around

the on land facilities and other areas.

5.4. ASSESSMENT OF INFRASTRUCTURE DEMAND

BCPL has identified the Infrastructure that shall be built as part of the proposed project. These

have been explained in the Project Description section.

5.5. AMENITIES/FACILITIES

BCPL intends to build a green field LNG Storage and regasification terminal at Kukrahati. In

addition to containing the all the standard facilities which may be required in a project of this

magnitude (like tanks, pipes, valves etc.), BCPL intends to provide amenities like drinking

water supply, sanitary spaces etc. for the personnel working onshore.

On the vessel, in order to face operative conditions, a number of people shall be housed on

board the vessel as per the DG Shipping guidelines, inclusive of technical personnel dedicated

to typical terminal operations (actual value will be defined in the later stage of the project).

Based on the actual number of people, accommodations may include the following:

• Public spaces: Separate dining room and lounge for officers, mess and lounge for crew, duty

mess, hospital/dispensary, gymnasium;

• Service spaces: galley, pantries for officers and crew, pantry at cargo control room, FSRU

and laundries, storage lockers, linen (clean, dirty) lockers, incinerator room, waste handling

room


52

• Sanitary spaces: public toilets, changing rooms for officers and crew

• Operational spaces: combined wheelhouse with chart and radio room, engine control room,

cargo control room with related meeting room, conference room, main administration office,

one (1) office each for Captain, C/Engineer and Senior Officers, document store, central fire

control station, fire equipment rooms

• Provisions stores: Dry provision (18°C), meat (-25 °C), fish (-25°C), vegetable (2°C), lobby

(4°C), bonded store.

6. PROPOSED INFRASTRUCTURE

6.1. INDUSTRIAL AREA

The proposed project site at Kukrahati is unlevelled ground. Before commencement of the

project, BCPL shall level the land. Once land levelling is completed, BCPL shall start activities

as per the project schedule. Once the requisite civil activities at the site are completed, BCPL

shall bring in the other project components like Vaporizers, tanks, pumps etc. and install the

same as per the planned layout. All season access roads, if needed, might be built by BCPL to

facilitate movement of vehicles from the main road till the project site.

6.2. RESIDENTIAL AREA

The terminal will have minimal working staff and the occupancy shall be limited to few skilled

/ semi-skilled (<50) and security personnel. All staff would work in shifts and apart from a

control room and rest room, no residential areas are planned within the terminal. The Vessel

shall have experienced crew onboard (as per DGS Manning requirements).

6.3. GREEN BELT

Green belt will be developed in the peripheral of the project site around the on land facilities

and other areas. Development will be finalized based on Chief Controller of Explosives

(CCoE)approval/ and considering the safety aspects & The Petroleum and Explosives Safety

Organization (PESO) regulations.

6.4. SOCIAL INFRASTRUCTURE

As per of the Corporate Social Responsibility plan, BCPL is committed to provide Social

Infrastructure in the area of operations. An interaction is required to understand the

community infrastructure needs of the area. BCPL will understand these needs better,

through further interactions. Based on the EIA Study which is being carried out for the


53

project, BCPL as a responsible corporate citizen will support either directly or through the

district administration – development of social infrastructure for the local communities. The

impact of the support will be reviewed periodically, monitored, and assessed. Necessary

project administrative offices/maintenance/ storage/ warehouse set up shall be made.

6.5. CONNECTIVITY

The identified project site at Kukrahati, lies in the Purba Medinipur district of West Bengal and

is well connected to the nearest Industrial hubs of Haldia and Falta, through roads and ferry

services, respectively.

The site is well-connected through rail/road network for transporting materials to the site. As

the site is adjacent to Hooghly estuary, river route will be utilized for transport of construction

materials as well as LNG vessels.

6.6. DRINKING WATER MANAGEMENT

BCPL will enable provision for drinking water management system at the site. After

completion of detailed engineering studies, BCPL shall finalize the number of tanks and other

specifications required for the construction of drinking water management system.

6.7. FIRE WATER STORAGE SYSTEM MANAGEMENT

Fire Protection facilities for the ORF will be designed primarily in accordance with OISD- 156,

supplemented by OISD-117. Main components of fire water system include fire water storage,

fire water pumps and firewater spray system (deluge).

Water for firefighting will be stored in two aboveground steel tanks/Underground Steel RCC

Tanks of each having 50% of required capacity above the level of suction point. The effective

firewater storage will be designed to cater 4 hours aggregate rated capacity of the firewater

pump. Two x 100% diesel driven firewater pumps (1 duty + 1 stand-by) will be provided to

meet the required fire water flow rate and head. Pumps will be quick starting type and start

automatically on pressure drop in the firewater network. Also provision of local push button

and remote actuation of firewater pumps from control room will be provided. Firewater

pumps (including jockey pump) will be designed in accordance with NFPA-20.


54

6.8. SEWAGE SYSTEM

BCPL will enable provision for sewage system at the site. After completion of detailed

engineering studies, BCPL shall finalize the number of sump pits and other specifications

required for the construction of sewerage system. Either a septic tank-soak pit system or, a

potable sewage treatment will be installed for treatment of sewage generated at the project

site in Kukrahati.

The FSRU/FSU will have a sewage treatment system to treat and discharge waste and meet

the MARPOL standards. Similarly, treatment facilities for bilge water will be provided on the

FSRU.

6.9. INDUSTRIAL & SOLID WASTE MANAGEMENT

Various kinds of solid and industrial wastes that will be generated on the vessel, will be either

safely incinerated or safely brought to site location and disposed in onshore waste facilities

available at Kukrahati. Food wastes generated on board the vessel where all plastic materials

have been removed will be comminuted or ground to a particle size capable of passing

through a screen with openings of 25mm and then discharged.

Both solid and industrial wastes from onshore facilities will be collected and either recycled or

safely disposed in nearby approved waste handling facility.

6.10. POWER REQUIREMENT & SUPPLY/SOURCE

Power requirement during construction phase will be approximately 3 MW and shall be

sourced from the local electricity grid. In case of non-availability of power from the local

grid/disruption of power, temporary DG sets with cumulative capacity of 3 MW shall be used.

The FSRU/FSU shall be self-sufficient and will have on board Power Generation of upto 40

MW, which shall be used to meet all power requirement onboard the FSU/FSRU including

those required for the LNG Handling facility onboard the vessel. In case of the land based tank

and vaporizer option the power requirement would be 20 MW and this power requirement

for the facilities on the jetty and the project site shall be met by the power supplied from the

West Bengal State Electricity Board (WBSEB) or from the power generated onboard the

FSRU/FSU or through gas/diesel gensets at project site. The boil off gas from the FSU/FSRU/

Onshore Storage shall be utilized for generation of power in case gas gensets are used.


55

7. REHABILITATION AND RESETTLEMENTS (R&R) PLAN

One part of the land belongs to Haldia Development Authority and is fully surrounded by

boundary wall. The land is free from any settlement and hence does not require any kind of

rehabilitation and resettlements.

The other part of the land is being used as a brick kiln and is being acquired directly from the

current owners.

8. PROJECT SCHEDULE AND COST ESTIMATES

8.1. SCHEDULE

Project Schedule for commissioning of the project is majorly divided in to following sections

as follows:

• Identification of suitable project site

• Conduct major studies and surveys

• Required clearances and permissions for the site and the project

• Chartering/purchase/fabrication of FSRU/FSU/onshore storage tanks and vaporizers

• Building Onshore Storage tanks

• RoU acquisition for onshore pipeline

• FEED and Detailed engineering for project facilities and onshore pipeline

• Procurement of long lead items and other materials

• Construction of site and onshore pipeline including civil works, electrical, mechanical,

instrumentation, control room, SCADA, communication and customer installation readiness

• Site readiness

• Pre-commissioning of project facilities

• Commissioning of the project

Considering all the above activities, project shall be implemented within shortest possible

time once all the permissions and clearance from state and central statutory bodies are

obtained. It is estimated that since the start of construction work it will take 24 months to

commission the project. Project is expected to commission by Q2 2021.


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8.2. PROJECT COST

Estimated CAPEX of the project is ~Rs. 2000 Crores that shall comprise of the following

components:

• Land and Land Development

• Studies

• Jetty & Jetty Regasification Unit

• Onshore Storage tanks

• On land facilities: Regasification Units, Truck loading, other ancillary systems

• LNG Transfer system including unloading arms, pipeline etc.

• Cryogenic pipelines, loading bay, metering, pumps etc.

• Floating assets

• LNG storage facilities/ Tanks/ Pumps/ Truck Loading Bay

• Water Intake, Pumping and outfall

• Firefighting system

• Onshore Facilities/Pipeline

• IDC

• Contingency

9. ANALYSIS OF THE PROPOSAL

As part of the proposed project development, following employment and goods/service

sourcing requirements can be locally met:

• Unskilled/semi-skilled workers required as part of constructing onshore facilities and laying

the onshore pipeline – for short term

• Land transport and local accommodation requirements for both construction and

operational personnel

• Security and patrolling requirements during operation of terminal and onshore pipeline


57

10. HEALTH, SAFETY, ENVIRONMENT AND COMMUNITY

The Project development will give highest consideration to the preservation of human life, the

minimization of environmental impacts and the mitigation of adverse effects on community.

The main risk for safety and environment are related to the handling of liquefied natural gas

(LNG) and pressurized natural gas (NG).

The main risk for safety and environment are related to the handling of LNG and pressurized

natural gas (NG). LNG hazards result from three of its properties: cryogenic temperatures,

dispersion characteristics, and flammability characteristics. In order to cope with these risks,

International Maritime Organization (IMO) issues the International Code for the Construction

and Equipment of Ships Carrying Liquefied Gases in Bulk (normally referred as IGC Code).

The Project Site falls under Seismic Zone IV classified as damage risk zone as per IS 1893-

2002. The design of the facility will be in accordance with relevant IS code. Suitable seismic

coefficients in horizontal and vertical directions respectively, would be adopted while

designing the structures as per NBC/IS codes and other statutory norms.

LNG is natural gas that has been refrigerated into a cryogenic liquid so that it can be shipped

long distances in dedicated Shuttle Vessels. Once an LNG Shuttle Vessel reaches a receiving

terminal, the LNG is unloaded and stored in FSRU/FSU until it is regasified and has been sent

to customers through natural gas pipeline. LNG is a hazardous liquid, because of its cryogenic

properties and combustibility (as natural gas). LNG hazards result from three of its properties:

cryogenic temperatures, dispersion characteristics, and flammability characteristics. The

extremely cold LNG (about -163°C) can directly cause injury or damage (brittle fracture). A

vapour cloud, formed by an LNG spill, could drift downwind into populated areas. It can lead

to ignition if the concentration of natural gas is between 5% and 15% in air in the presence of

an ignition source.

The natural gas generated by the LNG vaporization is a flammable gas mostly made up of

methane. The hazard related to NG releases is due to its highly flammability and the potential

formation of jet fires or flammable vapour clouds.

In order to cope with these risks, International Maritime Organization (IMO) issues the

International Code for the Construction and Equipment of Ships Carrying Liquefied Gases in

Bulk (normally referred as IGC Code). The IGC Code is an international mandatory code that


58

defines all the safety provisions to be foreseen and made available on board LNG Shuttle

Vessel as well as regasification units.

The IGC Code defines the minimum safety requirements for the ships handling liquefied gases

with particular reference to:

• Ship survival capabilities;

• Ship arrangement;

• Cargo containment, pressure and temperature control and venting;

• Process pressure vessels and piping;

• Material selection;

• Electrical installations;

• Fire protection / fire extinction;

• Personnel protection; etc.

In addition to IGC Code, Class Rules are applied providing additional safety features related to

structure design, testing, fabrication and ship survivability.

As far as the pollution risks are concerned, the terminal shall comply with the Intervention

Convention for the Prevention of Pollution from Ships (MARPOL). The MARPOL Convention

was adopted in 1973 and covers the pollution of the sea by oil, noxious substances carried by

ships, sewage and garbage produced on board. In particular, MARPOL requires the

preparation and implementation of a Shipboard Marine Pollution Emergency Plan (SMPEP)

that consist of a management and response plan in case of any spill into the water.

As far as on land facility safety is concerned, Indian laws as well as international standards will

be applied to minimize risks and ensure a safe work environment. Onshore safety strategy is

made up of:

• Application of engineering standards;

• Assessment of the risk.

The first step to ensure plant safety is the application of recognized engineering standards

that allow developing a design that has safety consideration built in. Since engineering

standards cannot cover and deal with all potential risks, the design will pass through a risk

assessment process that will aim to:


59

• Identify hazards;

• Identify potential incidental scenarios;

• Evaluate their potential likelihood;

• Assess consequences for each scenario;

• Calculate the resulting risk.

For those risks that result higher than the acceptable level, additional actions shall be

undertaken including:

• Assessment of risk reduction measures to lower the risk level both acting on the probability

of occurrence (prevention) or acting on the expected consequences (mitigation);

• Defining an inspection and monitoring program;

• Inform personnel on the risk identified and train personnel to manage it.

11. CODES AND STANDARDS

FSRU/FSU

The FSRU/FSU will be designed and realized according to main maritime rules and regulations,

including the following:

• The International Convention for the Safety of Life at Sea SOLAS (Consolidated Edition,

2009) and SOLAS Amendments 2010 -2011;

• The International Code for Construction and Equipment of Ships carrying Liquefied Gases in

Bulk "IGC Code" 1993 Edition and following Amendments up to Contract signing;

• International Convention on Load lines 1966, as amended by IMO ResolutionsA513

• (XIII) and A514 (XIII), inclusive of Protocol of 1988 Relating to the International Load Lines,

as modified by the 2003 Amendments and 2004 Amendments including MSC.172(79)

resolution (2005 Edition);

• IMO International Ship and Port Facility Security Code ISPS (2012 edition) and following

Amendments up to Contract signing;

• International Telecommunication Convention (Malaga - Torremolinos 1973) with Annex and

Revisions (Geneva, 1974 and Nairobi 1982) and following;

• International Convention for the Prevention of Pollution of seas from ships 1973 as

modified by the Protocol of 1978 relating thereto (MARPOL 73/78) Consolidated Edition2011;

• International Conference on Tonnage measurement of Ships, 1969 as amended by IMO


60

Resolutions A493 (XII) and A494(XII);

• International Convention for the Prevention of Collision at Sea (COLREG), 1972, as amended

by IMO Resolution A464 (XIII) and following (consolidated Edition2003);

• International Maritime Dangerous Goods Code (IMDG Code), 2012Edition;

• InternationalCodeforApplicationofFireTestProcedures,FTPCode(2012Edition)

• ILO Maritime Labour Convention, MLC 2006 (2006Edition);

• Suez Canal Authority: Tonnage Measurements and Navigating Rules;

• IMO Anti-Fouling Convention,2005;

• IMO Code on Alerts and Indicators, 1999 (2010 Edition) and following Amendments up to

Contract signing;

• IMO Code on Intact Stability, 2008 (2009Edition);

• IMO Noise Levels on Board Ship (1982Edition);

• IMO Resolution A343 (IX) Recommendation on Method of Measuring Noise Levels at

Listening Posts;

• IMO Resolution A468 (XII) Code Noise Levels on board Ships;

• IMO Resolution A 708 Navigation Bridge Visibility and Function;

• International Life-Saving Appliance Code LSA Code (2010Edition);

• IMO Publication No.978 - Performance Standards for Navigational Equipment (1988

Edition);

• IMO Recommendations of Equipment for the towing of disabled tankers (1981 Edition);

• IMO Recommendations Concerning Regulations for Machinery and Electrical Installations in

Passenger and Cargo Ships (Resolution A. 325 (IX) - 1976 Edition);

• IMO Graphical Symbols for Fire Control Plans (2006Edition);

• IMO Guidelines for the Provisional Assessment of Liquids Transported in Bulk (2006 edition);

• IMO Navtex Manual (2005Edition);

• Ballast Water Management Convention (2004Edition);

• IMO Ballast Water Management Convention and the Guidelines for its implementation

(2009Edition);

• International Aeronautical and Maritime Search and Rescue Manual (IAMSAR Manual)

2010Edition;


61

• Global Maritime Distress and Safety System Manual, GMDSS Manual (2010Edition);

• NACE Standard for Shipbuilding;

• Furthermore, the following guidelines will be taken into account:

• IACS REC No.47 Part A Shipbuilding and Repair Quality Standard for New Construction (To

be kept as minimum reference);

• ILO Codes of Practice n.152, Safety and Health in Dockwork, 1977 as amended 1979 and

following (1996Edition);

• Equipment and fittings required by O.I.L. rules 147, Minimum Standard Criteria for

Merchant Ships (1997Edition);

• ISO Standards – All the applicable ones;

• ISO 6954 (1984) Guidelines for the overall evaluation of vibration in merchant ships;

• ISO 8468 = 1990 (E) - Ship Bridge layout and associated - Requirements and Guidelines

(1990-11-01);

• ISO 6578 - Refrigerated Light Hydrocarbon Fluids - Static Measurement - Calculation

procedure;

• ISO 8311 - Refrigerated Light Hydrocarbon Fluids - Calibration of membrane tanks and

independent prismatic tank in ships – Physical measurement;

• ISO 8309 - Refrigerated Light Hydrocarbon Fluids - Measurement of liquid levels in tanks

containing Liquefied gases - Electrical Capacitance Gauges;

• ISO 8310 - Refrigerated Light Hydrocarbon Fluids - Measurement of temperature in tanks

containing Liquefied gases - Resistance Thermometers and Thermocouples;

• ISO 10574 - Refrigerated Light Hydrocarbon Fluids - Measurement of liquid levels in tanks

containing Liquefied gases - Float Type Level Gauges;

• ISO 13398 - Refrigerated Light Hydrocarbon Fluids - Liquefied Natural Gas - Procedure of

Custody Transfer System;

• G.I.I.G.N.L. - LNG Custody Transfer Handbook 3rd Edition2011;

• I.E.C. Publication No.92 (electric part);

• ISGOTT-InternationalSafetyGuideforOilTankersandTerminal(5thEdition,2006);

• ICS Bridge Procedures Guide (4thEdition);

• ICS Tankers Safety Guide (Liquefied Gas) (2nd Edition,1996);

• ICS Guide to Helicopter/Ship Operations (4thEdition);


62

• ICS Safety in Liquefied Gas Carrier(1980);

• ICS/OCIMF/SIGTTO LNG Ship to ship Transfer guide (Edition,2011);

• OCIMF/SIGTTO Manifolds Recommendation Liquefied Natural Gas Carriers (LNG)

(Edition2011);

• OCIMF Mooring Equipment Guidelines (3rd Edition,2011);

• OCIMF Effective Mooring (3rd Edition2008);

• OCIMF Recommendations on Equipment for the Towing of Disabled Tankers (2nd

Edition,1996);

• OCIMF Safety Guide for Terminals Handling Ships Carrying Liquefied Gases in Bulk (2nd

Edition,1993);

• OCIMF Prediction of Wind and Current Loads on VLCC’s (2nd Edition,1995);

• OCIMF Recommendations for the Tagging/Labelling, Testing and Maintenance,

Documentation/Certification for Ships’ Lifting Equipment(2005);

• OCIMF/SIGTTO Prediction of Wind Loads on Large Liquefied Gas Carrier(1985);

• SIGTTO Liquefied Gas Handling Principles on Ships and in Terminals (3rd Edition, 1999);

• SIGTTO Cargo fire-fighting on liquefied gas carrier (2nd Edition,1996);

• SIGTTO Guidelines for the alleviation of excessive surge pressure on ESD -1987.

• SIGTTO Recommendation for the Installation of Cargo Strainers on LNG Carriers -

January1984;

• SIGTTO Recommendation and Guidelines for Linked Ship/Shore Emergency Shut-Down of

Liquefied Gas Cargo Transfer - July1987;

• SIGTTO Introduction to the Design and Maintenance of Cargo System Pressure Relief Valves

on Board Gas Carrier, 2nd Edition(1998);

• SIGTTO Guidelines for Automatic Cargo Tank Overfill Protection Aboard Gas Carrier (1993);

• SIGTTO Guidelines for Ship to Shore Access for Gas Carrier;

• SIGTTO Information Paper No5: Ship/Shore Interface Communications (2nd Edition 1997);

• OCIMF/SIGTTO Inspection Guidelines for Ships Carrying Liquefied Gases in Bulk (3rd

Edition2005);

• I.M.P.A. Shipmaster’s guide to Pilot Transfer by Helicopter(1990);

• I.M.P.A. (International Maritime Pilot’s Associations) Pilot Ladders;


63

• SNAME T&R No.3-39 “Guide for Shop and Installation Test”,1985;

• SNAME T&R No.3-47 “Guide for Sea Trials”,1989;

• SNAME T&R 5-2 “Gas Trials Guide for LNG Vessels”.

Onshore Facility and Pipelines

The following standards will be followed for the design, construction and installation of

Onshore facility and Pipelines:

• ASME – American Society of Mechanical Engineers:

• ASTM – American Society for Testing and Materials;

• API – American Petroleum Institute;

• IS – Indian Standards;

• NFPA – National Fire Protection Agency;

• IEC – International Electro technical committee;

• ISO – International Standardization;

• PNGRB Standards and Regulations

BENGAL CONCESSIONS PRIVATE LIMITED ENVIRONMENTAL RESOURCES MANAGEMENT

1

LNG Regasification Terminal in


East Medinipur District, West Bengal

Prepared for: M/s Bengal Concessions Private Limited

Prepared by:

ERM India Pvt. Ltd.

July 2018


2

CONTENTS

1 INTRODUCTION 3

1.1 OBJECTIVES OF THE STUDY 3

1.2 STRUCTURE OF DRAFT TOR 4

1.2.1 Introduction 4

1.2.2 Project Description 4

1.2.3 Baseline Studies 4

1.2.4 Impact Assessment 8

1.2.5 Project Benefits 9

1.2.6 Additional Studies - Risk Assessment and Disaster Management Plan 9

1.2.7 Environmental Management Plan (EMP) 9

1.2.8 Environmental Monitoring Strategy 10

1.2.9 EIA Reporting 10


3

1 INTRODUCTION

Bengal Concessions Private Limited (BCPL) a subsidiary of H-Energy

Renewables Private Limited (HREPL), is planning to set up an LNG Storage

and regasification terminal at Kukrahati, West Bengal. The proposed LNG

terminal is initially envisaged to handle 0.3-3.0 MMTPA (Million Metric

Tonnes Per Annum) of Regasified Liquefied Natural Gas (RLNG) during the

first 5-6 years of operation and it capacity will be increased up to 5.0 MMTPA.

As part of this project, BCPL intends to construct a Jetty in the Hooghly river

to receive LNG by shuttle carriers, store it in an FSU or FSRU or on land and

re-gasify the LNG either in the FSRU or by a set of vaporizers on land or on

jetty at the project site at Kukrahati. The R-LNG thus produced shall be

supplied to Customers in the vicinity through suitable evacuation pipelines.

BCPL expects this project to be commissioned by Q2 - 2021.

The proposed project activity falls under the Category Oil & gas transportation

pipeline and LNG Terminal vide Notification dated 14th September, 2006) which

requires environment clearance from the Environmental Impact Assessment

Appraisal Committee (EAC) of the Ministry of Environment and Forests and

Climate Change (MoEFCC). To initiate the environmental clearance (EC)

process, BCPL has to submit Form-1 of the EIA Notification along with a

Terms of Reference (ToR) for the EIA for approval by the MoEFCC before

undertaking the EIA study.

ERM India Pvt. Ltd. is undertaking an environmental assessment of the

proposed FSU/FSRU based LNG Terminal and shall document the same as an

Environment Impact Assessment report. This draft Term of Reference (ToR)

intends to set the scope of the EIA study for the proposed LNG terminal

development activities. The intention of the proposed EIA is to support the

project for obtaining the necessary environmental clearance from the

MoEFCC. In this perspective, ERM would strive to fulfil the project objectives

delineated in the section below.

1.1 OBJECTIVES OF THE STUDY

The overall objectives of the EIA study will be as follows:

Establish the prevailing baseline environmental and socioeconomic

condition of the areas abutting the proposed LNG Terminal;

Assess environmental, socioeconomic and occupational health impacts

arising out of the construction and operation of the LNG Terminal;

Identify residual impacts that may arise from the project and suggest

suitable measures to minimize them;

Recommend appropriate preventive and mitigation measures to

minimize pollution, environmental and social disturbances during the

life-cycle of the project;


4

Formulate EMP that integrate mitigation measures with existing

program of project proponent so that they can be implemented,

monitored and suitable corrective action can be taken in case of

deviations;

Assess the risks associated with the project and suitably prepare a

Disaster Management Plan.

1.2 STRUCTURE OF DRAFT TOR

This draft ToR has been prepared in purview of the EIA study to be

undertaken for the proposed LNG Terminal. It has been based on Standard

ToR for EIA/EMP report for projects/Activities requiring Environmental

Clearance under EIA Notification, 2006, published in April, 2015. The draft

ToR submitted to Expert Appraisal Committee (EAC) will assist in finalization

of the ToR by MoEFCC. The other key purpose of the draft ToR is to identify

and convey the issues pertaining to environmental baseline monitoring,

impact assessment methodologies and draw environmental management plan

at a later stage.

The draft ToR for the EIA study is framed within the following structure:

1.2.1 Introduction

This section will include the purpose of the project, profile of the project

proponent, the provisions of the General Conditions of EIA Notification, 2006

that the project attracts, etc. Further the need for conducting the study and its

scope will be given here.

1.2.2 Project Description

This section of the EIA report will provide an overview of the project in terms

of:

Location of the LNG Terminal and environmental setting

Land availability for the LNG Terminal

Construction of LNG Terminal and associated facilities

Operation of the LNG Terminal

Resource requirement for construction and operation

Pollution sources and characterization during construction and

operation

1.2.3 Baseline Studies

Understanding of Project area

To provide an understanding of the project area the EIA study involves

reconnaissance visits and compilation of secondary information present as

following.

Location of the proposed project

Location of settlements in the vicinity


5

Location of sensitive environmental receptors (settlements,

waterbodies etc.) in the project area

A list of major industries with name and type within study area (10km

radius)

Location of National Parks, Sanctuaries, Biosphere Reserves, Migratory

Corridors of Wild Animals (if any) within 10 kms.

Details of drainage of the project up to 10km radius of study area.

Study Area

Intensive data collection are being conducted within the study area i.e. area

falling within the 10 km around the site from the centre point of the LNG

Terminal which may be impacted by the proposed development of the LNG

Terminal (Figure 1.1). 2 km surrounding the LNG Terminal shall be regarded

as core area and rest of the area of about 10 km boundary around the LNG

Terminal would be considered as buffer area. The following features are being

considered within the study area:

Present land use/land cover of core and buffer area

Topography of the study area

Sensitive environmental resources: sensitive natural habitats viz.

forests, waterbodies, streams/rivers etc.

Surface water resources and drainage network in the study area

Ground water resources in the project site and study area

Details of the physical and socio-economic features along with

manmade structures

Road Network

Proneness to Natural Disasters

Sensitive Social Resources: Human habitats, Public Utilities, Valuable

Common Property Resources.

The LNG Terminal and the surrounding study area would be depicted on GIS

maps through satellite imagery and topographical map to understand the

status of environment and their impacts. The following section details out the

Sampling Plan for the study.

Primary Monitoring

The sampling plan for primary monitoring is being drawn up based on the

findings of the reconnaissance survey and after obtaining an understanding of

the proposed project activities. The sampling plan also takes into

consideration the receptor locations that could potentially be affected by the

proposed activities. The tentative monitoring stations and sampling locations

for each environmental component along with the parameters being

monitored, frequency and number of samples being taken are presented in the

environmental matrix given in Table 1.1.


6

Table 1.1 Details of monitoring program for environmental components

Component Meteorology

No. of Stations 1 location

Frequency & Duration One season

Parameters Wind speed, Wind Direction, Rainfall, Temperature, Relative Humidity & Cloud Cover

Locations Adjacent to the project site

Component Air Quality

No. of Stations 8 locations

Frequency & Duration 24hrs / 8 hrs, 2 times a week for one season (excluding monsoon)

Parameters PM10, PM2.5, SO2, NOx, CO

Locations Sensitive receptors around the proposed site, considering micro-meteorological condition

Component Surface Water Quality


Frequency & Duration Grab sample – once in the season

Parameters

pH, temperature, turbidity, total hardness, total alkalinity, Electrical conductivity chloride, sulphate, nitrate, fluoride, sodium, potassium, salinity, total nitrogen, total phosphorus, DO, BOD, COD, phenol, PCB, HC, heavy metals, total coliform and faecal coliform, SAR, boron, mercury, cadmium, lead, Hexavalent Chromium (Cr+6) and Total Chromium (Cr)

Locations Hooghly River stretch in the study area

Component Potable Water Quality

No. of Stations 6 locations potable water sources in the villages


Parameters

As per IS 10500: 2012 standards and including heavy metals Antimony (Sb), Arsenic (As), Boron (B), Beryllium (Be), Cadmium (Cd), Copper (Cu), Lead (Pb), Mercury (Hg), Nickel (Ni), Zinc (Zn), Selenium (Se), Molybdenum (Mo), Hexavalent Chromium (Cr+6) and Total Chromium (Cr)

Locations From neighboring villages

Component Soil Quality



Parameters

Texture, pH, Electrical Conductivity, Cation Exchange Capacity, Porosity, Water Holding Capacity, Organic Carbon, Sodium Absorption Ratio (SAR), Nitrogen, Phosphorous, Potassium (NPK) Values, Copper, Zinc, mercury, cadmium, lead.

Locations One from the project site and four from neighboring locations

Component Ambient Noise


Frequency & Duration Once in the season over 24 Hours (daytime / night time)


7

Parameters Equivalent sound level in dB (A) – Leq

Locations Sensitive receptors around the ML area

Component Traffic


Frequency & Duration Once during study period

Parameters Heavy, medium and light vehicles

Locations Access and approach road to the project site

Proposed Monitoring Location Map of air, met is enclosed in Figure. 1.2, soil

and water quality monitoring locations are shown in Figure 1.3 and noise and

traffic locations are shown in Figure 1.4.

Secondary Studies

Desktop study will be conducted for understanding the topography,

geological settings like rock type, seismicity and associated hazards mainly in

the area will be studied as part of baseline study. Soil data including type,

classification, characteristics, soil properties, etc., will be important for

engineering design considerations.

Ecological Survey

The ecological profile of the area would be drawn up based on the review of

secondary data and primary field surveys. Secondary data will be obtained

from Forest Department and local people. Preliminary investigation and

studies show that there is no ecologically sensitive area within 10km of the

project site boundary. However, this will be further studied during the

primary ecological surveys to be undertaken at the project area and

surroundings as part of the EIA study.

The primary and secondary data relating to flora, fauna and agricultural

diversity of the area will be generated by visiting the site area and its

surroundings. The baseline surveys are being carried out to determine the

existing environmental conditions in order to facilitate an adequate

assessment of the Project’s impacts upon ecology and aids in further

identification and development of appropriate mitigation measures. Efforts

will also be made to find protected species in the area which can be of

conservation importance.

Socioeconomic Analysis

Assessment of the socioeconomic profile forms an integral part of any EIA

Study. The baseline socioeconomic scenario will focus on demographic

structure, economic activity, education, literacy profile, infrastructure facilities

of the villages located within the study area. Secondary data for this purpose

will be utilized from Census of India, 2011. Socioeconomic profiling will


8

involve diagnosis of baseline status of the villages of the study area in relation

to human environment with respect to:

Socio-Cultural resources - which refers to demographic structure, total

population, density, housing, sex ratio, literacy, employment level and

cultural facilities

Infrastructure resources - refers to educational facilities, health

services, transportation, water supply, communication, other service

etc.

1.2.4 Impact Assessment

The EIA study will aim to identify, characterize and evaluate potential

impacts arising out of the project and prioritize them so that they can be

effectively addressed through Environment Management Plans and by

adopting appropriate Project designing and planning.

Impact Identification

The preliminary identification of the potential impacts will be carried out

based on the understanding of the project gained during the scoping exercise

and also from the field visit, consultation with representatives of the project

proponent and professional judgment of the ERM team. A preliminary

understanding of the impacts from construction and operation of LNG

Terminal are provided below:

1. Air environment: Assessment of ground level concentration of

pollutants from the construction and operation of LNG Terminal. Air

Quality modelling will be undertaken to understand the additional

emissions due to the proposed development of the LNG Terminal. The

air quality contours shall be plotted on a location map showing the

location of project site, habitation nearby, sensitive receptors, if any.

2. Water Environment: Impact on surface water quality and ground

water quality will assessed due to surface runoff from construction

sites and cold water discharge during operation phase. Proposed

mitigation and control measures will be provided.

3. Soil Environment-Impact to the soil quality at the surrounding areas of

the LNG Terminal due to deposition of dust.

4. Local ecology- Impact to local ecology due to noise, lighting at the site.

Impact on aquatic ecology due to cold water discharge

5. Occupational Health: The imminent health hazards associated with

operation of the LNG Terminal. This will be dealt in the risk section.

6. Socio-cultural impact: The proposed project is new projects; socio-

cultural impacts are envisaged.

The environmental and health aspects will be studied in detail in EIA study

and relevant mitigation measures will be suggested.


9

Impact Evaluation

An environmental matrix will be developed to formally present an overview

of the predicted impacts. The matrix structure will take into account the

environmental issues as well as the concerns of the community.

The first step in the elaboration of the matrix will consist of defining the main

activities or aspects of the project that possibly can generate negative or

positive impacts through extensive consultations with representatives of the

project proponent. The second step will aim at establishing a list of

environmental elements (biophysical and human) found in the project area.

Potential interrelations between the impact sources and these elements will be

established to evaluate the impacts.

Environment Safeguards

The EIA study would prepare guidelines for mitigating any adverse impacts

identified due to the proposed project. The site specific mitigation plan will

specifically address impacts that would be generated as a result of the

proposed project.

1.2.5 Project Benefits

The benefits arising out of proposed development of the LNG Terminal will

be studied and provided in this section

1.2.6 Additional Studies - Risk Assessment and Disaster Management Plan

Risk analysis will be carried out for the facilities proposed in the development

plan in EIA studies. Potential hazards will be identified and consequence

analysis will be conducted as part of EIA study. The Disaster Management

Plan will be integrated with District Disaster Management Plan of East

Medinipur District.

1.2.7 Environmental Management Plan (EMP)

The Environmental Management Plan (EMP) will recommend specific,

structured and targeted management plans to mitigate the significant impacts

and bring them to a level that would be acceptable to both the regulatory

authorities and the community. The EMP would be laid down in a manner

that these plans can be integrated with the proponent’s existing environmental

management measures. The EMP would also include recommendations those

necessary for pollution prevention, control as well as conservation and

compensatory measures. In addition, a systematic environmental monitoring

plan for assessing the adequacy of the mitigation measures and for

understanding changes in environmental quality due to the proposed project

would also be part of the EMP.


10

1.2.8 Environmental Monitoring Strategy

To measure the effectiveness of the implementation of the EMP a monitoring

strategy (Plan) for activities during construction phase and also during the

post construction phase will be prepared. The Plan will include the

monitoring activities and corresponding schedules.

1.2.9 EIA Reporting

Reporting on all activities conducted during the project will be prepared,

collated and submitted in the form of an EIA Report. The report will include

supporting documents as necessary, a list of findings, impacts and proposed

mitigation measures. Following would be the structure of the report as per the

guideline set by the EIA 2006 Notification:

Executive Summary

Introduction

Description of Project

Description of Environment

Impact Assessment

Environmental Monitoring Program

Alternative Analysis

Additional Studies - Risk Assessment and Disaster Management Plan

Project Benefits

Environmental Management Plan & Framework

Summary and Conclusion

Disclosure of Consultants

The draft EIA report would be further finalized by incorporating comments

and views obtained from different stakeholders during the Public Hearing

and through letters/ representations before submitting it to the appraisal

committee. Apart from annexures to the report, there would also be notes and

proceedings of the public hearing, list of references and other relevant

documents, photographs etc.


11

Figure 1.1 Study Area of the proposed project


12

Figure 1.2 Proposed monitoring locations of Meteorology and Air Quality


13

Figure 1.3 Proposed monitoring locations of groundwater, surface water and soil


14

Figure 1.4 Proposed monitoring locations of Noise and Traffic

Point Latitude Longitude

A 22°11'30.00"N 88° 6'16.32"E

B 22°11'13.52"N 88° 6'31.31"E

C 22°11'12.62"N 88° 6'39.98"E

D 22°11'16.28"N 88° 6'40.15"E

E 22°11'18.03"N 88° 6'42.16"E

F 22°11'19.41"N 88° 6'45.67"E

G 22°11'21.87"N 88° 6'45.71"E

H 22°11'24.35"N 88° 6'36.22"E

I 22°11'26.52"N 88° 6'28.48"E

Project Location on Satellite Image

Documents

No: BCPL/BD/WBIGP/MoEFCC/EC-08 Aug 29, 2018 Ministry of ...environmentclearance.nic.in/writereaddata/... · Corporate office: 12th Floor, Knowledge Park, Hiranandani Business Park,