JETTY AND BREAKWATERS 1. LNG CAPACITY OF 11...

PRE-FEASIBILITY REPORT FOR

PROPOSED LNG & LPG IMPORT FACILITIES WITH CAPTIVE JETTY AND BREAKWATERS

1. LNG CAPACITY OF 11 MMTPA (PHASE I - 5.5 MMTPA,

PHASE II - 5.5 MMTPA) WITH OFFSHORE & ONSHORE STORAGE TANKS

2. LPG CAPACITY OF 4 MMTPA (PHASE I – 2.0 MMPTA,

PHASE II – 2.0 MMTPA) WITH OFFSHORE AND ONSHORE STORAGE TANKS

At

T. Challapalli (V), Uppalaguptam Mandal, East Godavari District, Andhra Pradesh, INDIA

Project Proponent:

M/s Hindustan LNG Limited 6-2-913/914,2nd Floor, Progressive Towers

Khairatabad, Hyderabad-500004, INDIA Mail : [email protected], [email protected]

Environment Consultant:

Bhagavathi Ana Labs Pvt. Limited

(A Bureau Veritas Group Company) 7-2-C-14, Industrial Estate, Sanathnagar,

Hyderabad 500018

mailto:[email protected]

Hindusthan LNG Limited Pre Feasibility Report

Bhagavathi Ana Labs Pvt. Ltd. (a Bureau Veritas Group Company) IND.BH.41.16.0310/HSR Rev. 00, Draft for submission to client 2/28

CONTENTS

EXECUTIVE SUMMARY ........................................................................................................... 4 1. INTRODUCTION OF THE PROJECT ................................................................................. 6 1.1. IDENTIFICATION OF PROJECT AND PROJECT PROPONENT. .................................. 6 1.2. BRIEF DESCRIPTION OF NATURE OF THE PROJECT ................................................ 7 1.3. NEED FOR THE PROJECT ............................................................................................ 7 1.4. DEMAND- SUPPLY GAP ................................................................................................ 7 1.5. IMPORTS VS. INDIGENOUS PRODUCTION ................................................................. 8 1.6. EMPLOYMENT GENERATION DUE TO THE PROJECT ............................................... 8 2. PROJECT DESCRIPTION. ................................................................................................. 9 2.1. TYPES OF PROJECT INCLUDING INTERLINKED AND INTERDEPENDENT PROJECT, IF ANY. .................................................................................................................... 9 2.2. LOCATION ...................................................................................................................... 9 2.3. DETAILS OF ALTERNATE SITES .................................................................................. 9 2.4. SIZE OR MAGNITUDE OF OPERATION .......................................................................15 2.5. PROJECT DESCRIPTION WITH PROCESS DETAILS .................................................15 2.6. RAW MATERIAL REQUIRED ........................................................................................16 2.7. RESOURCES OPTIMIZATION ......................................................................................16 2.8. AVAILABILITY OF WATER, ENERGY /POWER ............................................................16 2.9. QUANTITY OF WASTES TO GENERATED ..................................................................16 2.10. SCHEMATIC REPRESENTATIONS EIA ....................................................................17 3. SITE ANALYSIS ................................................................................................................18 3.1. CONNECTIVITY .............................................................................................................18 3.2. LAND FORM, LAND USE AND LAND OWNERSHIP .....................................................18 3.3. TOPOGRAPHY (ALONG WITH MAP) ............................................................................18 3.4. EXISTING LAND USE PATTERN ..................................................................................18 3.5. EXISTING INFRASTRUCTURE .....................................................................................18 3.6. SOIL CLASSIFICATION .................................................................................................18 3.7. CLIMATIC DATA FORM THE SECONDARY SOURCES. ..............................................18 3.8. SOCIAL INFRASTRUCTURE AVAILABLE .....................................................................20 4. PLANNING BRIEF .............................................................................................................21 4.1. PLANNING CONCEPT ...................................................................................................21 4.2. POPULATION PROJECTION ........................................................................................21 4.3. LAND USE PLANNING ..................................................................................................21 4.4. ASSESSMENT OF INFRASTRUCTURE DEMAND .......................................................21 4.5. AMENITIES/ FACILITIES ...............................................................................................21 5. PROPOSED INFRASTRUCTURE .....................................................................................22 5.1. INDUSTRIAL AREA (PROCESSING AREA) ..................................................................22 5.2. RESIDENTIAL AREA (NON PROCESSING AREA) .......................................................22 5.3. GREEN BELT.................................................................................................................22 5.4. SOCIAL INFRASTRUCTURE .........................................................................................22 5.5. CONNECTIVITY (TRAFFIC AND TRANSPORTATION ROAD/ RAIL/METRO/ WATER WAYS) ......................................................................................................................................22 5.6. SEWERAGE SYSTEM ...................................................................................................22 5.7. INDUSTRIAL WASTE MANAGEMENT ..........................................................................22



5.8. SOLID WASTE MANAGEMENT.....................................................................................22 6. REHABILITATION AND RESETTLEMENT (R & R) PLAN .................................................23 7. PROJECT SCHEDULE & COST ESTIMATES ...................................................................24 7.1. ESTIMATED PROJECT COST ALONG WITH ANALYSIS IN TERMS OF ECONOMIC VIABILITY OF THE PROJECT. .................................................................................................24 8. ANALYSIS OF PROPOSAL (FINAL RECOMMENDATIONS) ............................................25 8.1. FINANCIAL AND SOCIAL BENEFITS ............................................................................25 9. REFERENCE: ....................................................................................................................26

TABLE OF FIGURES

FIGURE 1: DEMAND SUPPLY GAP PROJECTION (MMSCMD) ....................................... 7 FIGURE 2: INDEX MAP SHOWING THE PROJECT SITE ................................................ 10

FIGURE 3: MAP OF THE AREA 10 KM AROUND THE PROJECT SITE ....................... 11

FIGURE 4: CAPTIVE JETTY MAP .......................................................................................... 12 FIGURE 5: CAPTIVE JETTY MAP WITH COORDINATES ................................................ 13

FIGURE 6: ENVIRONMENTAL SENSITIVITY MAP ............................................................ 14

TABLES

TABLE 1 : CLIMATOLOGICAL DATA STATION: IMD, KAKINADA ...........................................20 TABLE 2 : SUMMARY OF PROJECT DESIGN / DETAILS .......................................................27



EXECUTIVE SUMMARY

S .No Description Details

1. Name of the Project Proposed LNG and LPG import facilities with Captive Jetty & Breakwaters (a) LNG Capacity of 11 MMTPA (Phase I - 5.5 MMTPA, Phase II - 5.5 MMTPA) and Floating

Storage Unit (FSU), Land based Storage Tanks (240000 m³ each in 2 stages) and Truck Loading Terminal (12 Bay) (b) LPG capacity of 4 MMTPA (Phase I - 2.0 MMTPA, Phase II - 2.0 MMTPA) with Offshore

and Onshore Storage Tanks

2. Location and Features of the Terminal

T. Challapalli, Uppalaguptam Mandal, East Godavari District, Andhra Pradesh. Proposed Terminal : Rs.2800 Crores (Rupees Two thousand and Eight hundred Crores only) (a) LNG Capacity of 11 MMTPA (Phase I - 5.5 MMTPA, Phase II - 5.5 MMTPA) and Floating

Storage Unit (FSU), Land based Storage Tanks (240000 m³ each in 2 stages) and Truck Loading Terminal (12 Bay)

(b) LPG capacity of 4 MMTPA (Phase I - 2.0 MMTPA, Phase II - 2.0 MMTPA) with Offshore and Onshore Storage Tanks (1000m3 along with truck loading facilities) Project Features :

(1) Development of necessary facility/equipment for ship berthing and mooring, LNG, LPG unloading arms with all safety measures (2) LNG, LPG storage and transportation (3) LNG insulated Cryogenic Pipeline for onshore facility (4) LNG Re-gasification facilities (5) Truck loading facilities for LNG and LPG (6) Natural gas pipeline for connectivity to existing GAIL gas distribution grid. The imported LNG and LPG will be unloaded from the vessel into Floating Storage Unit (FSU). LNG and LPG is transferred and stored in the land based storage tanks. After Regasification (RLNG)



S .No Description Details

is transported to Gail Gas Grid for further delivery to the clients on the GAIL Pipeline Network. LNG will be also introduced in the transportation sector as an environmental friendly fuel, hence LNG truck loading terminal facilities are envisaged. Project is located at T. Challapalli (V), Survey No.1 Uppalaguptam Mandal, East Godavari District, Andhra Pradesh.India.

Latitude

Longitude

Jetty 16°27'14.3249"N

82°03'51.4617"E

LFP 16°27'23.9686"N

082°03'45.9478"E

GAIL Grid

16029’4.10”N 8205’26.10” E

TOPOSHEET No. : E44W2, E44W3, E44V14, E44V15

3. Production Liquefied Natural Gas of 11 MMTPA (in 2 Phases 5.5 MMTPA each ) capacity

4. Total land requirement for the project

330 Acres

5. Total Water requirement & Source

The water required for the proposed LNG terminal will be met from adjacent canal during construction and from sea during operations for regasification.

6. Manpower During Construction 500 and during operation 400 (direct & Indirect employment)

7. Estimated Cost of the Project Capital cost – Rs 2800 Crores (Rupees Two thousand and Eight hundred Crores only)



1. INTRODUCTION OF THE PROJECT

1.1. Identification of project and project proponent.

M/s Hindustan LNG Limited (HLNG) a registered company in Hyderabad, India is desirous of supplying natural gas. HLNG intends to import LNG and LPG import facilities with Captive Jetty & Breakwaters at T. Challapalli Village. (a) LNG Capacity of 11 MMTPA (Phase I - 5.5 MMTPA, Phase II - 5.5 MMTPA) and

Floating Storage Unit (FSU), Land based Storage Tanks (240000 m³ each in 2 stages) and Truck Loading Terminal (12 Bay) to store and transport the LNG, re-gasify and deliver natural gas at required pressure and temperature at the battery limits of Gas Authority of India Limited (GAIL).

(b) LPG capacity of 4 MMTPA (Phase I - 2.0 MMTPA, Phase II - 2.0 MMTPA) with Offshore

and Onshore Storage Tanks and transport facility. HLNG intends to use the proposed LNG T. Challapalli, Uppalaguptam Mandal, East Godavari District, Andhra Pradesh, India to import and store LNG; Further, HLNG intends to use pipeline for regular transfer of LNG packets from terminal to various customers; HLNG proposes to store the LNG packets at customer location, re-gasify as required and deliver natural gas to GAIL. The Regasified LNG will be supplied to Konaseema Gas Power Limited of 445 & 820 MW capacity located in Ravulapalem, near Rajahmundry, East Godavary District, Andhra Pradesh and also to the following gas based power generation plants located in the State of Andhra Pradesh, GMR Vemagiri (370 MW) and barge-mounted (237 MW), GVK’s Jegrupadu Extension (220 MW), Gauthami (464 MW), Lanco’s Kondapalli Stage-II (366 MW) Liquified Natural Gas (LNG) is the most environmental friendly fuel with a very high efficiency and most preferred fuel. The latest trends in the advanced countries all the transport vehicles are directly having LNG combustion facilities replacing diesel and petrol. We propose to market LNG to all the bulk transporters and also to the mining industry. The Andhra Pradesh State Road Transport Corporation (APSRTC) is having a fleet of 15000 buses and they have approached Hindustan LNG for installation of LNG facilities inorder to save on the fuel bills which will substitute diesel consumption. The Government of India (GOI) wants to provide LPG connections to the BPL households to ensure the universal coverage of cooking gas in the country to empower women and protect their health. As per the statistical survey of the GOI, the use of LPG Consumers being covered will be about 1.5 Crores. As on date, there is no LPG facility in the eastern part of India. This facility will support the GOI initiatives of LPG supply to BPL households as well as to others. . Also there are many other gas based projects in other sectors in the east coast of

Andhra Pradesh which are potential customers for us.



1.2. Brief description of nature of the project

The proposed LNG and LPG Import, loading and Floating Storage Unit of 11 MMTPA (in 2 Phases each 5.5 MMTPA ) Capacity at T. Challapalli, Uppalaguptam Mandal, East Godavari District, Andhra Pradesh falls in schedule 6(a) of category ‘A’.

1.3. Need for the Project

The forecasts of total domestic demand for gas (with the exception of the conservative IEP estimate), when compared with likely domestic supply of 150 MMSCMD, indicate a supply shortfall of at least 100 MMSCMD in the short term. Policy makers have pursued two options for meeting shortfalls in gas LNG imports and transnational pipelines.

1.4. Demand- Supply Gap

The world natural gas consumption growth rate in the last decade was over 2.76%, while in the Asia Pacific region it was 6.92% and for India 9%. This clearly indicates that the growth rate of primary energy consumption as well as natural gas consumption in India is higher compared to the World and Asia Pacific averages, consistent with the energy needs of growing economy. India needs to increase its energy supply by 3-4 times within the next two decades.

FIGURE 1: DEMAND SUPPLY GAP PROJECTION (MMSCMD)

In recent years the demand for natural gas in India has increased significantly due to its higher availability, development of transmission and distribution infrastructure, the savings from the usage of natural gas in place of alternate fuels, the environment friendly characteristics of natural gas as a fuel and the overall favorable economics of supplying gas at reasonable prices to end consumers. Power and Fertilizer sector remain the two biggest contributors to natural gas demand in India and continue to account for more than 50% of gas consumption. India can be divided into six major



regional natural gas markets namely Northern, Western, Central, Southern, Eastern and North-Eastern market, out of which the Western and Northern markets currently have the highest consumption due to better pipeline connectivity. However, with the 3 increasing coverage and reach of natural gas infrastructure in India, this regional imbalance is expected to get corrected. In future, the natural gas demand is all set to grow significantly at a CAGR of 7% from 226.7 MMSCMD in 2012-13 to 713.5 MMSCMD in 2029-30. This demand represents the Realistic Demand for natural gas in India.

1.5. Imports vs. Indigenous production

The supply of natural gas is also likely to increase in future with the help of increase in

domestic gas production and imported LNG. However, the expected increase in domestic production at present is significantly lower than earlier projections due to a steady reduction in gas output from the KG D6 field. The capacity of RLNG terminals in India is expected to increase from 13.60 MMTPA in 2012-13 to 73 MMTPA in 2029-30 assuming all the existing and planned terminals in India would materialize.

The availability of natural gas in India is expected to fall short of the total natural gas demand by around 81 MMSCMD in 2012-13. However, this shortfall will reduce by 2017-18 due to substantial addition in regasification capacity and natural gas supply through cross border pipeline (TAPI). The demand-supply gap is likely to again increase post 2017-18 and reach about 265 MMSCMD by 2029-30 as increase in supply lag behind a steady increase in demand.

1.6. Employment Generation due to the Project

The project will create the direct employment of 200 Peoples during the operation phase

of the project. During the construction phase, skilled and unskilled people on daily average 300 Peoples will be employed. HLNG will give preference to the local people during construction and operation phase of the project depending upon the skill, job requirement and capability. Several other indirect employment opportunities will be created in the surrounding areas viz., Transport, business, workshops, grocery & retails, medical, etc.



2. PROJECT DESCRIPTION.

2.1. Types of project including interlinked and interdependent project, if any.

The proposed LNG Import for 11 MMTPA (Phase I - 5.5 MMTPA, Phase II - 5.5 MMTPA)

with Land Based Storage Tanks (240000 m³ Each in 2 stages) and also LPG import for 4 MMTPA (Phase I - 2.0 MMTPA, Phase II - 2.0 MMTPA) and storage is located at T. Challapalli, Uppalaguptam Mandal, East Godavari District, Andhra Pradesh, India. The Project is conceived to supply Regasified Natural Gas (RLNG) to KGPL and other nearby IPPs viz., GVK, Lanco, Gautami, GMR also interlinked project like VBC Fertilizers & Chemicals Ltd etc through nearest GAIL Network injection Point which is very nearer to proposed Project site at T. Challapalli, Ravva Gas Basin. The imported LNG will be unloaded from the vessel into Floating Storage Unit (FSU). LNG is transferred and stored in the land based storage tanks. After Regasification (RLNG) is transported to Gail Gas Grid for further delivery to the clients on the GAIL Pipeline Network. LNG will be also introduced in the transportation sector as an environmental friendly fuel, hence LNG truck loading terminal facilities are envisaged. The imported LPG will be unloaded from the vessel into Floating Storage Unit (FSU). LPG is transferred and stored in the land based storage tanks. LPG will be also introduced in the transportation sector as an environmental friendly fuel, hence LPG truck loading terminal facilities are envisaged.

2.2. Location

M/s Hindustan LNG Limited, propose to set up LNG and LPG Terminals with Floating Storage Unit (FSU), storage tank and cryogenic tank loading at T. Challapalli. The proposed LNG and LPG terminals are located at a distance of 23 km in SE direction from Kotipalli railway station. The Rajahmundry Airport is at 60 km in NE direction from the proposed LNG terminal. The area is well connected by the road network. The LNG terminal is about 2.5 km in N direction from Amalapuram, S.Yanam road. NH216 is at a distance of 14km’s from the proposed site. The index map of the LNG terminal site is given in Figure 2. The location map is shown with the 10 Km radius from the periphery of the terminal boundary in Figure 3. The entire project area falls in Survey of India (SOI) Toposheet No. E44W2, E44W3, E44V14, E44V15.

2.3. Details of alternate sites

The Project is conceived to supply Regasified Natural Gas (RLNG) to KGPL and other nearby IPPs GVK, Lanco , Gautami, GMR etc through nearest GAIL Network injection Point is at a distance of 2 kms. which is very nearer to proposed Project site at T. Challapalli, Ravva Gas Basin. Environment Sensitivity Map is provided in Figure 4.



FIGURE 2: INDEX MAP SHOWING THE PROJECT SITE



FIGURE 3: MAP OF THE AREA 10 KM AROUND THE PROJECT SITE



FIGURE 4: CAPTIVE JETTY MAP



FIGURE 5: CAPTIVE JETTY MAP WITH COORDINATES



FIGURE 6: ENVIRONMENTAL SENSITIVITY MAP



2.4. Size or magnitude of operation

The proposed LNG Import, loading and Floating Storage Unit with a capacity 11 MMTPA (in 2 Phases each 5.5 MMTPA ). The LPG capacity of 4 MMTPA (Phase I - 2.0 MMTPA, Phase II - 2.0 MMTPA) with Offshore and Onshore Storage Tanks

2.5. Project description with process details

LNG at atmospheric pressure of -162°C will be transported by sea from LNG exporter by LNG vessels upto a maximum of 266000 m3 capacity at T. Challapalli. LNG will be unloaded at the rate of 24,000 m3 by using unloading arms at the dedicated LNG berth suitable for berthing and unloading upto a maximum of 266000 m3 capacity. Annual throughput of LNG at the jetty is expected to be 11 MMTPA (in 2 Phases each 5.5 MMTPA). The unloaded LNG will be pumped through dedicated pipelines to the LNG Floating storage unit. Capacity of LNG storage tanks will be firmed up after detailed feasibility of the LNG terminal.

LNG Storage and Handling Operation o Imported LNG will be stored in a dedicated Floating Storage Unit (FSU) which

will be permanently berthed alongside dedicated LNG Jetty. o Shuttle LNG tanker will carry the imported LNG cargo from load port and offload

the cargo to FSU using flexible cryogenic hoses or unloading arms. The utilization of proven concept of FSU worldwide, will reduce the construction time of storage tanks (construction period of LNG storage tanks usually takes a minimum of 36 months) which is the main hurdle with respect to the time in setting up an LNG import terminal.

o LNG from FSU will be pumped to onshore tanks phase-wise (two numbers 2,40,000 m3) using cryogenic pumps and cryogenic hoses.

o LNG from the onshore tanks will be pumped after Regasification (RLNG) is transported to Gail Gas Grid for further delivery to the clients on the GAIL Pipeline Network.

o LNG is directly transported from the LNG Terminal Point to the delivery clients by LNG truck tankers.

LPG at atmospheric pressure of 0.5 to -45°C will be transported by sea from LPG exporter by LPG vessels upto a maximum of 80000 m3 capacity at T. Challapalli. LPG will be unloaded at the rate of 12,000 m3 by using unloading arms at the dedicated LPG berth suitable for berthing and unloading upto a maximum of 80,000 m3 capacity. Annual throughput of LPG at the jetty is expected to be 4 MMTPA (in 2 Phases each 2 MMTPA). The unloaded LPG will be pumped through dedicated pipelines to the LPG Floating storage unit and land based storage facilities. Capacity of LPG storage tanks will be firmed up after detailed feasibility of the LPG terminal.

LPG Storage and Handling Operation o Imported LPG will be stored in a dedicated Floating Storage Unit (FSU) which will

be permanently berthed alongside dedicated LPG Jetty. o Shuttle LPG tanker will carry the imported LPG cargo from load port and offload

the cargo to FSU using unloading arms. The utilization of proven concept of FSU worldwide, will reduce the construction time of storage tanks (construction period



of LPG storage tanks usually takes a minimum of 36 months) which is the main hurdle with respect to the time in setting up an LPG import terminal.

o LPG from FSU will be pumped to onshore tanks phase-wise (two numbers 80,000 m3) using cryogenic pumps and arms.

o LPG from the onshore tanks will be pumped to Truck Loading Facilities for road transport.

o LPG is directly transported from the LPG Terminal Point to the delivery clients by LPG truck tankers.

Topography and Drainage

The area prospected is almost flat with gentle undulations and gradually sloping. The maximum and minimum elevation recorded in the area taken up for investigations are as follows:

Maximum: 5 m MSL Minimum: 12 m MSL

2.6. Raw material required

The LNG Unloaded will be transported through pipeline and Trucks. The LPG will be unloaded and distributed by trucks.

2.7. Resources optimization

There will not be any waste generation, spillage etc as the LNG is carried through pipeline. There will not be any waste generation, spillage etc as the LPG is carried through pipeline.

2.8. Availability of water, Energy /power

Water requirement during Construction will be around 22.5 KLD (45lts * 500 workers) which will be sourced from the nearby village Panchayat. Construction water will be taken from nearby canal.

Water requirement during operation will be met from sea water for regasification facilities

through desalination plant. Power requirement is 3 MW during operation which will be sourced from APEPDCL.

2.9. Quantity of wastes to generated

Flaring will be carried out only during Emergency. No waste generation during normal operation.



2.10. Schematic representations EIA

Detailed schematic representations of the feasibility covering the purpose of EIA will be

given in the Environmental Impact Assessment report.



3. SITE ANALYSIS

3.1. Connectivity

There is good connectivity through road to the existing project site.

3.2. Land form, land use and land ownership

The land is vacant land with Survey number: 1 in T. Challapalli Village. The project proponent owns this land.

3.3. Topography (along with map)

The topography of the land is undulating from 5AMSL to 12 AMSL. It belongs to the toposheet no: E44W2, E44W3, E44W6. The toposheet of the project area is provided as Figure 7.

3.4. Existing land use pattern

No Reserve forest within the 10 kms from the proposed LNG and LPG terminal site

3.5. Existing infrastructure

Communication facilities such as telephone, tele-fax and Internet are not available in vicinity of the proposed terminal area.

3.6. Soil classification

Predominantly the texture of the soil is Sandy clay. Sand, slit and clay percentage ranges form 61-69%, 17-30% and 8-21% respectively.

3.7. Climatic data form the secondary sources.

The secondary data has been collected from IMD Kakinada, which is nearest IMD station to the project site. The data collected from IMD includes wind speed, wind direction, (recorded in sixteen directions), temperature, relative humidity, atmospheric pressure; rainfall and cloud cover over a period of 10 years. The monthly maximum, minimum and average values are collected. The collected data is tabulated in below.

The average annual rainfall in the region based on the IMD data is 1042.1 mm. The southwest monsoon generally sets in during the last week of May. About 30.9% of the rainfall is received during the southwest monsoon. The rainfall gradually increases after July. The Northeast monsoon sets in the month of October and contributes to the rainfall by about 52.5% of the total rainfall. The maximum number of rainy days occur in the months of October and then in November. Annual and monthly variations in the rainfall are given in Table-1.



FIGURE 7: TOPO MAP



TABLE 1 : CLIMATOLOGICAL DATA STATION: IMD, KAKINADA

Month

Atmospheric Pressure (Mb)

Temperature (0C)

Relative Humidity (%) Rainfall

(mm) 0830 1730. Max. Min. 0830 1730

January 1013.4 1010.2 29.9 19.9 86 65 7.3

February 1011.8 1008.5 32.2 21.1 80 60 1.4

March 1010.0 1006.4 34.7 23.1 76 61 5.2

April 1007.4 1003.6 37.2 25.7 71 65 14.4

May 1003.6 999.8 39.4 27.9 62 55 49.7

June 1002.5 998.8 37.9 28.1 62 49 44.1

July 1003.0 999.4 35.5 26.7 69 56 80.0

August 1003.7 1000.0 35.0 26.4 70 57 94.8

September 1005.3 1001.5 34.8 25.9 73 63 103.4

October 1008.0 1004.8 32.4 24.7 82 75 272.0

November 1011.0 1008.2 29.9 22.5 85 76 275.2

December 1013.1 1010.1 28.9 20.7 87 72 94.6

3.8. Social Infrastructure available

All infrastructure facilities such as education, health facilities and other social facilities are adequate at district headquarter.



4. PLANNING BRIEF

4.1. Planning Concept

As the project is envisaged to employ 300 indirect employees during Construction and at

the operation phase to employ 200 direct employees. The basic infrastructure facilities like medical facilities, schools, playground, drinking facilities, bank, post offices etc. will be developed and the same can also be used by nearby villages

4.2. Population projection

The Proposed LNG and LPG terminal at T. Challapalli would aid in the overall social and

economic development of the region. The terminal will give direct employment to about 200 people, in addition there will be indirect employment to many more people in the form of out sourcing jobs, business opportunities, service facilities etc. This will enhance the economic status of the local region.

Apart from the jobs, the company will provide medical and educational facilities to the

employees which can also be availed by the people around the terminal.

4.3. Land use planning

The land will be utilized for LNG and LPG facilities of which 33% will be left for Greenbelt.

4.4. Assessment of Infrastructure Demand

Adequate physical and social facilities will be developed as part of CSR in this area.

4.5. Amenities/ Facilities

All infrastructure facilities such as education, health facilities and other social facilities

are adequate at district headquarter which site makes the region adequate in amenities



5. PROPOSED INFRASTRUCTURE

5.1. Industrial Area (Processing Area)

Infrastructures are required for LNG and LPG Terminal activates with allied facilities.

5.2. Residential Area (Non Processing Area)

No residential area is proposed for the terminals.

5.3. Green belt

Afforestation will be done all along the periphery of terminal boundary for development of

green belt. 10-m width green belt will be developed.

5.4. Social Infrastructure

HLNG has well-defined CSR policy to Carryout social development and welfare

measures in the surrounding villages. Under CSR activity HLNG will initiate community development projects, in the fields of health, education and environmental preservation, in the study area around the terminal lease area.

5.5. Connectivity (Traffic and Transportation Road/ Rail/Metro/ Water ways)

The proposed LNG and LPG terminal is located at a distance of 27 km in SE direction from Kotipalli railway station. The Rajahmundry Airport is at 60 km in NE direction from the proposed LNG and LPG terminal. The area is well connected by the road network. The LNG terminal is about 2.5 km in N direction from Amalapuram - S.Yanam road. NH216 is at a distance of 14km’s from the proposed site. Kakinada port is at a distance of 70km’s.

5.6. Sewerage system

Domestic sewage generated by the terminal workers will be treated in STP. No other

effluents will be generated during constructional and operational phase of terminal.

5.7. Industrial waste management

On a regular basis, there is no generation of any non-hazardous or inert solid waste from

the proposed LNG and LPG terminals. A small quantity i.e. about 0.5 KL/year of hazardous oily waste will be generated from the proposed LNG terminal during periodic maintenance. Hazardous waste is being collected and stored at specific identified area at site. Authorized agency will be hired to dispose the collected Hazardous waste.

5.8. Solid waste management

No solid waste will be generated during operation. Solid waste generated during

construction will be treated through soak pits.



6. REHABILITATION AND RESETTLEMENT (R & R) PLAN Not applicable, since there is no R& R Issue involved.



7. PROJECT SCHEDULE & COST ESTIMATES 12 months from the date of obtaining all statutory clearances.

7.1. Estimated project cost along with analysis in terms of economic viability of the

project is (approx) Rs.2800 Crores (Rupees Two thousand and Eight hundred

Crores only).



8. ANALYSIS OF PROPOSAL (FINAL RECOMMENDATIONS)

8.1. Financial and social benefits

Based on the growing demand in the state of Andhra Pradesh over the next 10 years,

the proximity of the project location to this market is an advantage with respect reduction in freight of LNG to these markets. The financial viability also shows a good Rate of return from the project. Considering the above, HLNG is planning to go ahead with the project, once it gets all the statutory approvals

Employment: Preference will be given for locals for employment based on qualifications

& requirement Medical facilities: Medical facilities will be provided for employees as well as people of

nearby villages Educational facilities: Basic educational and vocational facilities will be provided for the

children of employees as well as nearby villagers Infrastructure facilities: Approach roads will be developed at par with plant roads Additional: The establishment of project will facilitate additional auxiliary facilities like

banking, post office & recreation facilities



9. REFERENCE:

http://www.gastechnology.org/Training/Documents/LNG17-proceedings/6-4-A_K_Balyan.pdf





TABLE 2 : SUMMARY OF PROJECT – PHASE WISE

FSU / FSRU

1. Location : T. Challapalli, Uppalaguptam Mandal, East Godavari District, Andhra Pradesh, India

2. Capacity Peak For LNG : Phase 1 : 5.5 MMTPA Phase 2 : 5.5 MMTPA

For LPG : Phase 1 : 2.0 MMTPA Phase 2 : 2.0 MMTPA

3. Peak Send Out Approx 786 MMSCFD / 22 MMSCMD of each phase.

4. Operating Pressure

65- 98 bar(g)

5. LNG Storage Capacity

Max 240000 M³

6. Regas Technology

Open Loop

7. HP Gas Outlet Temperature

0 - 50 ° C

8. Spare Philosophy

Operating + Standby for Critical Equipment

9. Flaring Flaring will be done in Emergencies

10. Staff / Crew Composition

Operation Phase : 40 Persons for FSU / FSRU on board

ISLAND JETTY

1. Location DATUM : WGS-84, ZONE-44, CM-81

WATER DEPTH AT PROPOSED JETTY LOCATION IS APPROX. 8m

ID EASTING NORTHING LATITUDE LONGITUDE

Land Fall Point (LFP)

613450.36 1819747.51 16°27'23.9686"N 82°3'45.9478"

E

Proposed Jetty Location

613615.44 1819452.00 16°27'14.3249"N 82°3'51.4617"

E

2. Marine Area 35.5 Ha(Approx)

3. Jetty Dimension 300 x 25 m

4.Jetty Height 9.5 m from Chart Datum ( CD)

5. LNG Unloading from LNGC to FSU

Ship to Ship transfer using 8 Cryogenic Flexible hoses

6. Land Based Storage Tanks

240000 M³

7. A. HP Arm B. LP Arm

2 No.(for FSRU) 6 No (for FSU)

8. Power Requirement

1000 KVA

9. Navigation Exclusion Zone

350 m ( from FSU manifold)

10 Safety Exclusion Zone

500 m ( from FSU manifold)



11 Staff Unmanned, controlled from ORF and FSU

SUBSEA PIPELINE

1. Diameter 28 “

2. Design Pressure 98 bar (g)

3. Pipeline Length ( Jetty to ORF)

1.5 kms (approx) subsea and 0.5 kms on shore

Connectivity to Existing Gas Grid

1. Pipe Diameter 24 “

2. Operating Pressure

60-90 bar (g)

3. Gas Pipeline Length

4 Kms ( approx)

Onshore Receipt Facility (ORF)

1. ORF Location T. Challapalli, Uppalaguptam Mandal

2. Area 200 Acres

3. Gas Handling Capacity

22 MMSCMD

4. Power Requirement

800 KVA

5. Staff Operation Phase - 15 ( 5 on General Shift, 3 for each shift)

DREDGING

1. Navigation Channel Width

265 m ( existing channel width 160 m )

2. Turning Basin Diameter

600 m

3. Navigation channel , Turning basin and breathing area depth

15.5 m below CD

4. Capital Dredging

Estimated about 19 million M³

5. Maintenance Dredging

FSU basin : 1.5 million M³ (approx) per annum

Resource Requirement

1. Cooling Water At maximum Operation : 18000 M³ / hr of sea water as heating medium for LNG vaporization and 4750 M³ / hr for machinery cooling (Open Loop Mode)

2. Portable Water 22.5 KLD (45lts * 500 workers)

3. Power 3 MW (for ORF & Jetty) to be taken from Grid Power. FSU will be self sustained for power

4. Construction Material: Concrete & Steel

ORF : approx. 1000 M³ Jetty : approx 9000 M³

ORF : approx. 250 MT Jetty : approx 20000 MT

OTHER

1. Visiting LNG Carrier Ships

Maximum of 266,000 M³

JETTY AND BREAKWATERS 1. LNG CAPACITY OF 11...

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